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Home My WebLink About221-046Nolan Vlahovich Hilcorp North Slope, LLC GeoTechnician 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: 12/29/2025 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL API# 50231200790000 WHISKEY GULCH 1 (PTD 221-046) Whiskey_Gulch_1_TOC and Plug Tag 20 Jun 25 Please include current contact information if different from above. 221-046 T41229 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.29 13:55:00 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/26/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250826 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 24 50133206390000 214112 7/15/2025 AK E-LINE PPROF T40803 BR 11-86 50733207370000 225057 7/30/2025 AK E-LINE Hoist T40804 BR 11-86 50733207370000 225057 8/4/2025 AK E-LINE Perf T40804 BR 11-86 50733207370000 225057 8/9/2025 AK E-LINE Perf T40804 BRU 212-35T 50283200970000 198161 8/4/2025 AK E-LINE Perf T40805 BRU 212-35T 50283200970000 198161 6/28/2025 AK E-LINE Perf T40805 BRU 224-34T 50283202050000 225044 8/2/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 8/5/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 7/27/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 8/2/2025 AK E-LINE Punch T40806 KTU 43-6XRD2 50133203280200 205117 7/26/2025 AK E-LINE Perf T40807 MPL-13A 50029223350100 223017 8/10/2025 READ CaliperSurvey T40808 NCIU A-21 50883201990000 224086 1/14/2025 AK E-LINE Plug/Perf T40809 ODSN-16 50703206200000 210053 8/10/2025 READ CaliperSurvey T40810 PBU 01-30A 50029216060100 225050 8/7/2025 HALLIBURTON RBT-COILFLAG T40811 PBU 06-11A 50029204280100 225042 7/13/2025 HALLIBURTON RBT-COILFLAG T40812 PBU 11-37A 50029227160100 219062 7/27/2025 HALLIBURTON RBT T40813 PBU 14-43A 50029222960100 225041 7/31/2025 HALLIBURTON RBT-COILFLAG T40814 PBU F-06B 50029200970200 225054 8/5/2025 HALLIBURTON RBT-COILFLAG T40815 PBU L1-10A 50029213400100 225032 8/1/2025 HALLIBURTON RBT-COILFLAG T40816 PCU 02A 50283200220100 224110 7/27/2025 AK E-LINE Perf T40817 SRU 241-33 50133206630000 217047 7/28/2025 AK E-LINE Perf T40818 WhiskeyGulch 1 50231200790000 221046 6/18/2025 AK E-LINE Packer T40819 Please include current contact information if different from above. T40819WhiskeyGulch 1 50231200790000 221046 6/18/2025 AK E-LINE Packer Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.27 08:12:23 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________WHISKEY GULCH 1 JBR 08/20/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 CMV 8 had to be serviced- passed retest. 5K test. Test Results TEST DATA Rig Rep:Tyson RentonOperator:Hilcorp Alaska, LLC Operator Rep:Brad Whitten Rig Owner/Rig No.:Hilcorp 401 PTD#:2210460 DATE:7/2/2025 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopAGE250708095440 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4 MASP: 802 Sundry No: 325-329 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 FPNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 7 1/16"P #1 Rams 1 2 3/8 x 3 1/2"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 1 2 1/16"P Kill Line Valves 3 2 1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2550 200 PSI Attained P16 Full Pressure Attained P32 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@1650 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P5 #1 Rams P3 #2 Rams P3 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0       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: Run packer 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 10,271 feet See Schematic feet true vertical 9,332 feet N/A feet Effective Depth measured 2,790 feet 1220 & 2020 feet true vertical 2,571 feet 1215 & 1940 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 2,050' MD 1,965' tVD Swell Pkr; 1,220 MD 1,215' TVD Packers and SSSV (type, measured and true vertical depth)PermaPkr 2,020' MD 1,940' TVD SSSV: 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: 4,790psi N/A 5,210psi 6,890psi 1,501' 1,488' Burst Collapse N/A 2,470psi Production Liner 7,702' 2,730' Casing Structural 6,805' 4-1/2" 7,702' 10,268' 9,331' 120'Conductor Surface Intermediate 16" 10-3/4" 120' 1,501' measured TVD 7-5/8" 8,430psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 221-046 50-231-20079-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL392666 Whiskey Gulch Undfined Gas Whiskey Gulch 01 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 120' 0 00 0 00 0 Chad Helgeson, Operations Engineer 325-329 Sr Pet Eng: 7,500psi 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 chelgeson@hilcorp.com 907-777-8405 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 2:51 pm, Jul 14, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.07.14 14:19:55 - 08'00' Noel Nocas (4361) BJM 9/25/25 Page 1/1 Well Name: Whiskey Gulch 1 Report Printed: 7/9/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-231-20079-00-00 Field Name:Whiskey Gulch (WG)State/Province:ALASKA Permit to Drill (PTD) #:221-046 Sundry #:325-329 Rig Name/No: Jobs Actual Start Date:6/18/2025 End Date: Report Number 1 Report Start Date 6/18/2025 Report End Date 6/19/2025 Last 24hr Summary PTW/PJSM. MIRU AK E-line. Install 7-1/16" swab valve. PU lub and P-test PCE to 250/2,000 psi. Dump bail 50 gal cement on top of CIBP at 2,790'. SDFN. Report Number 2 Report Start Date 6/20/2025 Report End Date 6/21/2025 Last 24hr Summary PTW/PJSM. Tag TOC at 2,752.5' with 4.5" gauge ring. LD lub and SDFN. Report Number 3 Report Start Date 6/22/2025 Report End Date 6/23/2025 Last 24hr Summary PTW/PJSM. SIWHP 800 psi. PT PCE 250/2,000 psi. Run 6.25" GR/JB to 2,200'. Set permanent packer assembly at 2,020.75' (X-nipple with PX plug at 2,038.5' and bottom of WLEG at 2,050'). RDMO AK E-line. Bleed SIWHP to 194 psi to negative test packer. Report Number 4 Report Start Date 6/23/2025 Report End Date 6/24/2025 Last 24hr Summary SIWHP 195 psi. Bleed pressure down to zero. Monitor with Crystal gauge. Report Number 5 Report Start Date 6/24/2025 Report End Date 6/25/2025 Last 24hr Summary PTW, JSA. Spot in hot oi truck and Cruz 100 bbl vac truck loaded with 6% KCL from G&I facility. Check wellhead pressure 0 psi. RIg up hot oil truck with 1502 high pressure hose and 1502 swedge via pump in sub on flow line. Pressure test pump lines 250/3500 psi. Pump 100 bbls of 6% KCL. Walk pressure up to 1800 psi. Steady bleed off. Open well to open top and allow air bubbles to surface. 45 minutes for fluid and air to swap out. Back online down tubing at 1 bbl/min. Pressure up to 1800 psi. Monitor pressure. AT 1300 hrs pressure was stabalizing at 1761 psi. Start 10 minute test as per procedure. (1500 psi required). 1310 hrs end pressure test at 1750 psi. Recover graph and data. Bleed down WHP to zero. Shut in to check for pressure build. Open to vent to visually confirm no flow. Secure well. RDMO hot oil turck and Cruz Vac truck. Report Number 6 Report Start Date 7/1/2025 Report End Date 7/2/2025 Last 24hr Summary Arrive on location,check well, WHP 0 psi. Lay out liner, MIRU 401. Raise and scope up derrick, set auxiliary equipment and rig up. Nipple down tree, install test hanger w/ blanking sub, nipple up 7-1/16" BOP. M/u 2-7/8" test joint. Fluid pack BOPE, shell test 250/5000psi, good test. Secure well, SDFN. Report Number 7 Report Start Date 7/2/2025 Report End Date 7/3/2025 Last 24hr Summary PTW, PTSM. Set and rig up pipe skate, load w/ 2-7/8" 6.5# L 80 EUE 8 RD tubing. Strap and tally completion string. Test BOPE w/ 2-7/8" test joint, test annular 250/2500psi, test all other BOPE components to 250/5000psi, 5 minutes each test. Had one fail/pass on test #3, CMV #8 was leaking by. Greased valve re-tested, test passed. Test witnessed by AOGCC Inspector Adam Earl. P/u seal assembly and single in hole w/ 2-7/8" EUE. Sting into packer at 2016', running seals in and latching puting 4k down, placing bottom of seal assembly at 2023'. Pressure up on IA to 500psi to ensure seal assembly is holding. Calculate space out lay out necessary joints, m/u pups and hanger. Land hanger, RILD. Pressure test IA and tubing to 1500psi for 30 min each, good tests. Install TWC and secure well, SDFN. Report Number 8 Report Start Date 7/3/2025 Report End Date 7/4/2025 Last 24hr Summary PTW, PJSM. Nipple down BOP. Clean and prep wellhead. Install and nipple up tree. Test void and tree to 5000psi, 10 minutes each, good tests. Remove TWC from hanger and secure well. Remove and load auxiliary equipment from containment. Lower and lay over mast. Fold up liner. Mobilize rig 401 package to Susan Dionne pad. Report Number 9 Report Start Date 7/6/2025 Report End Date 7/7/2025 Last 24hr Summary PTW/PJSM. 0 psi SITP. MIRU Pollard Slickline. PT lubricator 250 psi low / 2500 psi high - good test. Swab fluid from surface to plug @ 2,039'. Recovered 11.4 of 12 calculated bbls. Jumper gas to 420 psi SITP. RIH w/ 2 7/8" GS and recover A-stop. RIH w/ 2" BS (short core) and pull prong, blown up hole. Well equalized at 750 psi. POOH and lost tool string at surface w/ 20' wire left in hole. Secure well, SDFN. Report Number 10 Report Start Date 7/7/2025 Report End Date 7/8/2025 Last 24hr Summary PTW/PJSM. 780 psi SITP. RU Pollard Slickline. PT lubricator 250 psi low / 2500 psi high - good test. RIH w/ 2.25" LIB and tag TOF @ 2,020'- impression of rope socket and wire. RIH w/ 2" JDC (split skirt) and recover tool string fish and prong (no wire). RIH w/ 3-prong wire grab (baited) and recover ~ 8' wire. RIH w/ 2.29" LIB and tag plug @ 2,044'- impression of plug (no wire). RIH w/ 2 7/8" GS and recover plug. RIH w/ 2.25" GR and tag TOC @ 2,763' RKB. Secure well, RDMO Pollard. _____________________________________________________________________________________ Updated by DMA 07-14-25 SCHEMATIC Well: Whiskey Gulch 1 PTD: 221-046 API: 50-231-20079-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T10 2,064 2,078 1,976 1,990 1402/17/22 Open T14A 2,890 2,910 2,653 2,669 2002/16/22 Isolated T18 3,373 3,381 3,045 3,053 801/11/22 Isolated T48 4,4984,5183,9653,9812012/28/21 Isolated T48 4,544 4,564 4,003 4,019 2012/29/21 Isolated T65 6,137 6,161 5,313 5,333 2412/27/21 Isolated T65 6,143 6,155 5,319 5,331 1212/22/21 Isolated OPEN HOLE / CEMENT DETAIL 10-3/4Est. TOC @ Surface (100% excess) Returns to surface (8/12/21) 7-5/8" 9-7/8 hole: 333bbls 12.0ppg Type I-II lead cement followed by 30bbls 15.8ppg Type I-IItail cement. No losses. 10bbls spacer back to surface (40 bbls spacer pumped). Volumetric ToC based on spacer returns = ~750 MD. CBL on 8/29/21 shows ToC TOC @ ~1430. 4-1/2TOC @ 7,404 (Tagged) CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven to Set Depth 84 X-56 Weld 15.01Surf 120 10-3/4Surf Csg 45.5 L-80 DWC/C 9.950Surf 1,501 7-5/8" Int. Csg 29.7 L-80 CDC 6.875Surf 7,702 4-1/2" Abandonment Lnr 12.6 L-80 IBT 3.958 7,538 10,268 2-7/8Tubing 6.5 L-80 8RD EUE 2.441Surf 2,050 JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 18 18 2.441Tubing hanger A 1,220 1,215 6.875 9.950 7-5/8 Swell Packer 2 2,020 1,940 4.0 6.875 WL Set 7-5/8 x 4 permapack w/ snap latch seal assembly (6/22/25) (6.37 stung in packer 3 2,038 1,955 2.313 3.67X nipple 4 2,050 1,964 2.441 3.67WL Entry Guide 5 2,790 2,571CIBP (2/17/22) w/ 25ft of cement (6/18/25) 6 3,180 2,888CIBP (2/16/22) 7 3,630 3,254 7-5/8 Composite Bridge Plug (magnum) 8 4,790 4,205 7-5/8 Composite Bridge Plug (magnum) 9 7,538 6,640 1.875 4.500Halliburton BHKA Disconnect Tool 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: Whiskey Gulch #1 (PTD# 221-046) Sundry # 325-329 Wireline tag Date:Tuesday, July 1, 2025 4:11:00 PM Chad, Cement plug length is >25’ requirement based on the logs, so that condition of approval has been satisfied. Notwithstanding any other requirements, the well has sufficient cement thickness to place the well on production. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Tuesday, July 1, 2025 2:03 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: Whiskey Gulch #1 (PTD# 221-046) Sundry # 325-329 Wireline tag Bryan, As required in the Sundry for Whiskey Gulch #1 completion it was requested to provide the logs for the tag of the bridge plug and the TOC. Please find attached logs for the plug, plug was set at 2790’ and cement was dumped on June 18th. We tagged the cement on the 20th at 2752.5’ with a 4.5” gauge ring. I also wanted to provide you with an update to the change on the completion for the well. We are not going to install a GL mandrel or use N2 for unloading the well as described in steps 14, 18-21. We will run a jewelry free completion to the packer. The plan is to swab the fluid off the well, pressure up the well with gas from Whiskey #14 well, and then pull the plug. We do not plan to flow the well until facilities and pipeline are completed in September, but the rig is working now, so we are moving forward with this workover. We will need your blessing to flow the well after you have had time to review these logs. Please let me know if you need anything else. Chad Helgeson Operations Engineer Kenai Asset Team 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: _Run packer___ 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): 10,271'N/A Casing Collapse Structural Conductor Surface 2,470psi Intermediate 7,500psi Production Liner N/A 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 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. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY N/A 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 ADL 392666 221-046 50-231-20079-00-00 Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 1,488' Size 120' 7-5/8"7,702' 1,501' MD 4-1/2" See Attached Schematic 8,430psi 5,210psi 120' 6,805' 120' 1,501' June 11, 2025 10,268'2,730' N/A 9,331' Perforation Depth MD (ft): 7,702' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Whiskey Gulch 01CO 790A Same ~802psi See Schematic Length N/A N/A 9,332'2,790'2,571' Whiskey Gulch Whiskey Gulch Undefined Gas 16" 10-3/4" See Attached Schematic m n P s 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-329 By Gavin Gluyas at 8:44 am, May 28, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.05.27 15:45:15 - 08'00' Noel Nocas (4361) 10-404 DSR-6/3/25BJM 6/5/25 X BOP test to 2500 psi. Verify 25' of cement on top of plug, CCL from CIBP tag and TOC tag. Send log results to AOGCC and obtain approval before putting well on production. A.Dewhurst 06JUN25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.06 11:18:20 -08'00'06/06/25 RBDMS JSB 061025 Well Prognosis Well Name: Whiskey Gulch #1 API Number: 50-231-20079-00-00 Current Status: SI Gas Well Permit to Drill Number: 221-046 First Call Engineer: Chad Helgeson (907) 777-8405 (O)(907) 229-4824 (C) Second Call Engineer: Scott Warner (907) 830-8863 Maximum Expected BHP: 853 psi @ 2763’ MD Based on 1yr BHP survey 2/1/23 Max. Potential Surface Pressure: 802 psi (Based on 0.023 psi/ft gas gradient to surface) Applicable Frac Gradient: NA – One zone open and no proposed perfs Shallowest Potential Perf TVD: NA see above Top of Pool per CO 790A: Whiskey Gulch Undefined Gas Pool Well Status: SI gas well Brief Well Summary: Whiskey Gulch -01 is an exploration well drilled near Anchor Point, originally looking for oil, which was unsuccessful, the lower 4-1/2” completion was abandoned in August of 2021. Hilcorp tested the gas sands individually looking for gas in a new field in the 7-5/8” casing. The testing found one productive sand near the top of the wellbore and has been shut-in while looking for additional gas in adjacent wells to justify economics of the facilities and pipeline installation. The purpose of this sundry is to run tubing and install new tree, and prepare the well for production when facilities and pipeline have been completed. Hilcorp requests a variance from 20AAC25.265(c)(1) for the SSV being in the vertical run of the tree. The typical Kenai land based well has the SSV located in the horizontal run, immediately off the wing valve. The well still has 2ea master valves. Wireline work is regularly completed on these wells and common for a cap string to be installed in the well in the future preventing the SSV to be in the vertical run. Wellbore Conditions: Pressure – 802 psi Current open perfs: 2,064-2078’ Procedure: 1. Review all approved COAs 2. RU Eline and PT 7” Lubricator 250 psi low / 2000 psi high 3. PU cement bailer and place 25ft of cement (~50 gal) on the plug at 2790’. Note: None of the zones below current plug at 2790’ had any hydrocarbons that would sustain any production. 4. PU 6.25” GR to drift well for packer to 2100’ 5. PU permanent packer with tail pipe and tested PX plug set in X nipple. Completion equipment: WL entry guide, 10ft pup joint, X nipple (loaded with PX Plug), 6-10’ Pup joint, Packer with snap latch assembly 6. RIH and set packer using Baker 20 setting tool with WL Entry guide @ ~2,050’. 7.Perform negative test on packer and plug. Bleed well down to 0 psi. (current pressure @ 802 psi) 8. Mix 100bbls of 6% KCl, pump into well 9.Pressure test packer to 1500 psi (hold for 10 min) 10. MIRU Hilcorp rig #401, Provide AOGCC 24hrs advance notice of BOP testing 11. Set BPV/TWC & N/D tree Tag TOC with <4.5" OD drift. Verify 25' of cement on top of plug. Variance approved. -bjm Tag top of CIBP at 2790'. -Verify depth for TOC tag comparison. -bjm Note: None of the zones below current plug at 2790’ had any hydrocarbons that would sustain any production. Well Prognosis 12. N/U BOP & pressure test 250 psi low / 2500 psi high a. A 5000 psi will be completed if BOP stack hasn’t been used in previous 6 months b. Test with 2-7/8” test joints 13. Pull BPV/TWC 14. PU sealbore extension and GL mandrel with dummy, RIH on 2-7/8” 8RD EUE tubing 15. RIH to packer, space out, and stab into seals and land hanger 16. PT Packer and tubing 30 min to 1500 psi (charted) 17. RDMO 18. MIRU SL, RIH and pull dummy from GL mandrel, install pocket protector 19. RU N2 pump, PT lines to 3500 psi 20. Use N2 to unload fluid form the well, through GL mandrel 21. Once fluid is recovered ~90 bbls SD N2 pump, leaving ~800 psi on well 22. RIH and confirm fluid level 23. Pull pocket protector and reinstall dummy GL valve 24. RIH and pull prong & plug from well. 25. Bleed N2 off well 26. Install Production facilities 27. Test SVS per 20AAC25.265, when facilities are complete and well is online. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Proposed Wellhead 4. Rig 401 7” BOP stack 5. 660ft radius map (no SSSV required for this well) _____________________________________________________________________________________ Updated By: CJD 04/27/22 SCHEMATIC Well: Whiskey Gulch 1 PTD: 221-046 API: 50-231-20079-00-00 PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status T10 2,064’2,078’1,976’1,990’14’02/17/22 Open T14A 2,890’2,910’2,653’2,669’20’02/16/22 Isolated T18 3,373’3,381’3,045’3,053’8’01/11/22 Isolated T48 4,498’ 4,518’ 3,965’ 3,981’ 20’12/28/21 Isolated T48 4,544 4,564 4,003 4,019 20’12/29/21 Isolated T65 6,137’6,161’5,313’5,333’24’12/27/21 Isolated T65 6,143’6,155’5,319’5,331’12’12/22/21 Isolated OPEN HOLE / CEMENT DETAIL 10-3/4”Est. TOC @ Surface (100% excess) Returns to surface (8/12/21) 7-5/8" 9-7/8” hole: 333bbls 12.0ppg Type I-II lead cement followed by 30bbls 15.8ppg Type I-II tail cement. No losses. 10bbls spacer back to surface (40 bbls spacer pumped). Volumetric ToC based on spacer returns = ~750’ MD. CBL on 8/29/21 shows ToC TOC @ ~1430’. 4-1/2”TOC @ 7,404 (Tagged) CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 10-3/4”Surf Csg 45.5 L-80 DWC/C 9.950”Surf 1,501’ 7-5/8"Int. Csg 29.7 L-80 CDC 6.875”Surf 7,702’ 4-1/2"Abandonment Lnr 12.6 L-80 IBT 3.958”7,538’10,268’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 1,220’1,215’6.875”9.950”7-5/8” Swell Packer 2 2,790’2,571’CIBP 3 3,180’2,888’CIBP 4 3,630’3,254’7-5/8” Composite Bridge Plug (magnum) 5 4,790’4,205’7-5/8” Composite Bridge Plug (magnum) 6 7,538’6,640’1.875”4.500”Halliburton BHKA Disconnect Tool Swell packer leaks -bjm _____________________________________________________________________________________ Updated By: CAH 05/22/25 PROPOSED Well: Whiskey Gulch 1 PTD: 221-046 API: 50-231-20079-00-00 PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status T10 2,064’2,078’1,976’1,990’14’02/17/22 Open T14A 2,890’2,910’2,653’2,669’20’02/16/22 Isolated T18 3,373’3,381’3,045’3,053’8’01/11/22 Isolated T48 4,498’4,518’3,965’3,981’20’12/28/21 Isolated T48 4,544 4,564 4,003 4,019 20’12/29/21 Isolated T65 6,137’ 6,161’ 5,313’ 5,333’ 24’12/27/21 Isolated T65 6,143’6,155’5,319’5,331’12’12/22/21 Isolated OPEN HOLE / CEMENT DETAIL 10-3/4”Est. TOC @ Surface (100% excess) Returns to surface (8/12/21) 7-5/8" 9-7/8” hole: 333bbls 12.0ppg Type I-II lead cement followed by 30bbls 15.8ppg Type I-II tail cement. No losses. 10bbls spacer back to surface (40 bbls spacer pumped). Volumetric ToC based on spacer returns = ~750’ MD. CBL on 8/29/21 shows ToC TOC @ ~1430’. 4-1/2”TOC @ 7,404 (Tagged) CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 10-3/4”Surf Csg 45.5 L-80 DWC/C 9.950”Surf 1,501’ 7-5/8"Int. Csg 29.7 L-80 CDC 6.875”Surf 7,702’ 4-1/2"Abandonment Lnr 12.6 L-80 IBT 3.958”7,538’10,268’ 2-7/8”Tubing 6.4 L-80 8RD EUE 2.441”Surf 2050’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 18’18’2.441”Tubing hanger 2 1,220’1,215’6.875”9.950”7-5/8” Swell Packer 3 ±2,000’±1,923’2.380”Gas lift mandrel 4±2,030’±1,948’2.441”6.875”WL Set 7-5/8” x 4” permapacker w/ snap latch seal assembly 5 ±2,040’±1,957’2.313”3.5”X nipple 6 ±2,050’±1,965’2.441”3.5”X Nipple & WL Entry Guide 7 2,790’2,571’CIBP (2/17/22) w/ 25ft of cement 8 3,180’2,888’CIBP (2/16/22) 9 3,630’3,254’7-5/8” Composite Bridge Plug (magnum) 10 4,790’4,205’7-5/8” Composite Bridge Plug (magnum) 11 7,538’6,640’1.875”4.500”Halliburton BHKA Disconnect Tool Whiskey Gulch #1 Proposed Wellhead 01/20/2025 Starting head, Cactus C-29L, 16 3/4 3M x 16'’ SOW, w/ 2- 2 1/16 5M SSO Multi-bowl, Cactus MBS-2- PS, 16 3/4 3M x 11 5M, w/ 4- 2 1/16 5M SSO 16'’ 7 5/8'’ 10 ¾’’ Tubing head, Cactus C-HPS, 11 5M x 7 1/16 5M, w/ 2- 2 1/16 5M SSO Valve, Master, WKM-M, 3 1/8 5M FE, HWO, DD trim Valve, Upper master, WKM-M, 3 1/8 5M FE, HWO, DD trim Valve, Swab, WKM-M 3 1/8 5M FE, HWO, DD trim BHTA, Otis, 3 1/8 5M FE x 6.5 Otis quick union top Tubing hanger, Cactus-EN-CL, 7 x 3 1/2 EUE 8rd lift and susp, w/ 3'’ type H BPV profile Adapter, Cactus-EN, 7 1/16 5M Stdd x 3 1/8 5M prepped for 5 ½ extended neck hanger 3 ½’’ or 2 7/8'’ These two are same annulus tubing x 7 5/8 will just blind off the lower and put valve on upper tubing head to make it easy for operations Whiskey Gulch #1 16 x 10 ¾ x 7 5/8 x 2 7/8 EQUIPMENT HEIGHT 99.09" ADDITION FOR RING GASKETS TOTAL STACK HEIGHT 2 each @ 0.50" 99.59" OPEN AND CLOSE DATA OPEN CLOSE 2-1/16" 5M HCR 0.61 0.52 HEIGHT DATA AND WEIGHT DATA 7-1/16" 5M ANNULAR 3.21 4.57 7-1/16" 10M RAMS (PER SET) 1.3 1.3 ϳͲϭͬϭϲΗϱDEEh>Z^,&&Z ^dz> ,/',d͗ϯϬ͘ϵΗ t/',d͗ϯϬϰϮ>^ ϳͲϭͬϭϲΗϱDdzW hKW ,/',d͗ϰϰ͘ϭϵΗ t/',d͗ϲϰϬϬ>^ ϳͲϭͬϭϲΗϱDdzWh^d< ϳͲϭͬϭϲΗϱDZ/>>/E' ^WKK> ,/',d͗ϮϰΗ t/',d͗ϭϲϬϬ>^ </>>^/͗Ϯ,ϮͲϭͬϭϲΗϱDD's ,K<^/͗ϭ,ϮͲϭͬϭϲΗϱDD's Eϭ,ϮͲϭͬϭϲΗϱD,Z S004S015W Sec. 23 Whiskey Gulch Pad Whiskey Gulch #1 Anchorage Homer Nikiski Seward Whiskey Gulch #1 Legend Whiskey_Gulch_1 Whiskey Gulch #1_660ft Buffer Other Surface Well Locations Well Paths Map Date: 5/27/2025 080160 Feet Document Path: O:\AWS\GIS\Dropbox\Julieanna Potter\Project_Handoff\Project_Handoff.aprxNAD 1927 StatePlane Alaska 4 FIPS 5004 Whiskey Gulch #1 660-ft Radiusu 1:2,500 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No Well Log Information: Digital Med/Frmt ReceivedStart Stop OH / CH Comments Log Media Run No Electr Dataset Number Name Interval List of Logs Obtained:Mudlogs, WLD logs, OHWireline- Bhvol, SWCore, Sonic, MicroImager, CBL 8/29/2021, Perf logs, XRMI YesYes YesMud Log Samples Directional Survey REQUIRED INFORMATION (from Master Well Data/Logs) DATA INFORMATION Log/ Data Type Log Scale DF 9/7/202190 10271 Electronic Data Set, Filename: Whiskey Gulch 1 LWD Final.las 35591ED Digital Data DF 9/7/2021 Electronic File: Whiskey Gulch 1 LWD Final MD.cgm 35591ED Digital Data DF 9/7/2021 Electronic File: Whiskey Gulch 1 LWD Final TVD.cgm 35591ED Digital Data DF 9/7/2021 Electronic File: DSR Actual - Whiskey Gulch #1_Plan.pdf 35591ED Digital Data DF 9/7/2021 Electronic File: DSR Actual - Whiskey Gulch #1_VSec.pdf 35591ED Digital Data DF 9/7/2021 Electronic File: Whiskey Gulch #1 - Definitive Survey Report.pdf 35591ED Digital Data DF 9/7/2021 Electronic File: Whiskey Gulch #1 - Final Surveys.xlsx 35591ED Digital Data DF 9/7/2021 Electronic File: Whiskey Gulch #1_DSR.txt35591EDDigital Data DF 9/7/2021 Electronic File: Whiskey Gulch #1_GIS.txt35591EDDigital Data DF 9/7/2021 Electronic File: Whiskey Gulch 1 LWD Final MD.emf 35591ED Digital Data DF 9/7/2021 Electronic File: Whiskey Gulch 1 LWD Final TVD.emf 35591ED Digital Data DF 9/7/2021 Electronic File: Whiskey Gulch 1 LWD Final MD.pdf 35591ED Digital Data DF 9/7/2021 Electronic File: Whiskey Gulch 1 LWD Final TVD.pdf 35591ED Digital Data DF 9/7/2021 Electronic File: Whiskey Gulch 1 LWD Final MD.tif 35591ED Digital Data Friday, February 23, 2024AOGCC Page 1 of 15 Whiskey Gulch 1 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 9/7/2021 Electronic File: Whiskey Gulch 1 LWD Final TVD.tif 35591ED Digital Data DF 9/7/2021 Electronic File: EMFView3_1.zip35591EDDigital Data DF 9/7/2021 Electronic File: Readme.txt35591EDDigital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_CBL_29AUG21.dlis 35592ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_CBL_29AUG21.pdf 35592ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_CBL_29AUG21_img.tiff 35592ED Digital Data DF 9/8/20211344 5299 Electronic Data Set, Filename: WHISKEY_GULCH_1_BHV_22AUG21.las 35593ED Digital Data DF 9/8/20217661 10290 Electronic Data Set, Filename: WHISKEY_GULCH_1_BHV_29AUG21.las 35593ED Digital Data DF 9/8/20218250 9950 Electronic Data Set, Filename: WHISKEY_GULCH_1_SW CORE_29AUG21.las 35593ED Digital Data DF 9/8/202114 1491 Electronic Data Set, Filename: WHISKEY_GULCH_1_WAVE_11AUG21.las 35593ED Digital Data DF 9/8/2021110 1503 Electronic Data Set, Filename: WHISKEY_GULCH_1_WAVE_11AUG21_Proces sedLog-V1.las 35593ED Digital Data DF 9/8/20211450 5299 Electronic Data Set, Filename: WHISKEY_GULCH_1_WAVE_22AUG21.las 35593ED Digital Data DF 9/8/20211490 5296 Electronic Data Set, Filename: WHISKEY_GULCH_1_WAVE_22AUG21_Proces sedLog-V1.las 35593ED Digital Data DF 9/8/20217680 10276 Electronic Data Set, Filename: WHISKEY_GULCH_1_WAVE_29AUG21.las 35593ED Digital Data DF 9/8/20217680 10275 Electronic Data Set, Filename: WHISKEY_GULCH_1_WAVE_29AUG21_Proces sedLog-V1.las 35593ED Digital Data DF 9/8/20211504 5300 Electronic Data Set, Filename: WHISKEY_GULCH_1_XRMI_22AUG21.las 35593ED Digital Data DF 9/8/20217710 10276 Electronic Data Set, Filename: WHISKEY_GULCH_1_XRMI_29AUG21.las 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_BHV_22AUG21.pdf 35593ED Digital Data Friday, February 23, 2024AOGCC Page 2 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_BHV_22AUG21_img.tiff 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_BHV_29AUG21.pdf 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_BHV_29AUG21.tif 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_SW CORE_29AUG21.pdf 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_SW CORE_29AUG21_img.tiff 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_11AUG21.pdf 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_11AUG21_img.tiff 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_11AUG21_Proces sedLog-V1.dlis 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_11AUG21_Proces sedLog-V1.pdf 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_11AUG21_Proces sedLog-V1_img.tiff 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_11AUG21_Wavef orm_CH-4.dlis 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_22AUG21.pdf 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_22AUG21_img.tiff 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_22AUG21_Proces sedLog-V1.dlis 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_22AUG21_Proces sedLog-V1.pdf 35593ED Digital Data Friday, February 23, 2024AOGCC Page 3 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_22AUG21_Proces sedLog-V1_img.tiff 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_22AUG21_Wavef orm_CH-4.dlis 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_29AUG21.dlis 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_29AUG21.pdf 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_29AUG21_img.tiff 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_29AUG21_Proces sedLog-V1.dlis 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_29AUG21_Proces sedLog-V1.pdf 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_29AUG21_Proces sedLog-V1_img.tiff 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_WAVE_29AUG21_Wavef orm_CH-4.dlis 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21.pdf 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21_img.tiff 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_XRMI_29AUG21.dlis 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_XRMI_29AUG21.pdf 35593ED Digital Data DF 9/8/2021 Electronic File: WHISKEY_GULCH_1_XRMI_29AUG21_img.tiff 35593ED Digital Data DF 9/13/202110 10350 Electronic Data Set, Filename: Whiskey Gulch 1.las 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Daily Reports.pdf 35645ED Digital Data Friday, February 23, 2024AOGCC Page 4 of 15 Whiskey Gulch 1.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 9/13/2021 Electronic File: Whiskey Gulch 1 Final Well Report.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Drilling Dynamics Log MD 2in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Drilling Dynamics Log MD 5in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Drilling Dynamics Log TVD 2in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Drilling Dynamics Log TVD 5in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Formation Log MD 2in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Formation Log MD 5in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Formation Log TVD 2in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Formation Log TVD 5in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Gas Ratio Log MD 2in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Gas Ratio Log MD 5in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Gas Ratio Log TVD 2in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Gas Ratio Log TVD 5in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 LWD Combo Log MD 2in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 LWD Combo Log MD 5in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 LWD Combo Log TVD 2in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 LWD Combo Log TVD 5in.pdf 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Drilling Dynamcis Log MD 2in.tif 35645ED Digital Data Friday, February 23, 2024AOGCC Page 5 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 9/13/2021 Electronic File: Whiskey Gulch 1 Drilling Dynamcis Log MD 5in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Drilling Dynamcis Log TVD 2in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Drilling Dynamcis Log TVD 5in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Formation Log MD 2in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Formation Log MD 5in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Formation Log TVD 2in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Formation Log TVD 5in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Gas Ratio Log MD 2in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Gas Ratio Log MD 5in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Gas Ratio Log TVD 2in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Gas Ratio Log TVD 5in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 LWD Combo Log MD 2in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 LWD Combo Log MD 5in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 LWD Combo Log TVD 2in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 LWD Combo Log TVD 5in.tif 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey1.dbf35645EDDigital Data DF 9/13/2021 Electronic File: whiskey1.hdr35645EDDigital Data DF 9/13/2021 Electronic File: Whiskey1.mdx35645EDDigital Data DF 9/13/2021 Electronic File: whiskey1r.dbf35645EDDigital Data DF 9/13/2021 Electronic File: whiskey1r.mdx35645EDDigital Data Friday, February 23, 2024AOGCC Page 6 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 9/13/2021 Electronic File: Whiskey1_SCL.DBF35645EDDigital Data DF 9/13/2021 Electronic File: Whiskey1_SCL.MDX35645EDDigital Data DF 9/13/2021 Electronic File: WHISKEY1_tvd.dbf35645EDDigital Data DF 9/13/2021 Electronic File: WHISKEY1_tvd.mdx35645EDDigital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (1).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (10).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (11).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (12).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (13).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (14).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (15).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (16).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (17).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (2).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (3).zip 35645ED Digital Data Friday, February 23, 2024AOGCC Page 7 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (4).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (5).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (6).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (7).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (8).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey_Gulch_1_Geolog_Formation_Photos (9).zip 35645ED Digital Data DF 9/13/2021 Electronic File: Whiskey Gulch 1 Show Reports.pdf 35645ED Digital Data DF 11/12/20211566 5247 Electronic Data Set, Filename: WHISKEY_GULCH_1_XRMI_22AUG21_1530- 5247_XRMI_Beds_Fractures_Dips.las 35945ED Digital Data DF 11/12/20211565 5249 Electronic Data Set, Filename: WHISKEY_GULCH_1_XRMI_22AUG21_1530- 5247_XRMI_FRACTURE_FREQUENCY.las 35945ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21I_PROC ESSED.ver 35945ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21_1530- 5247_XRMI_Beds_Fractures_Dips.csv 35945ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21_1530- 5247_XRMI_PROCESSED.dlis 35945ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21_1530- 5247_XRMI_PROCESSED.ver 35945ED Digital Data Friday, February 23, 2024AOGCC Page 8 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21_1530- 5247_XRMI_RAW.dlis 35945ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21_1530- 5247_XRMI_RAW.ver 35945ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21_1to20_S TATIC_DYNAMIC.pdf 35945ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21_1to20_S TATIC_DYNAMIC_img.tiff 35945ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21_PROCE SSED.dlis 35945ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21_RAW.dli s 35945ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_22AUG21_RAW.ve r 35945ED Digital Data DF Interpretation files not required under 20 AAC 25.071, will not be released. M.Guhl 2/23/2024 35945ED Digital Data DF 11/12/20217716 10209 Electronic Data Set, Filename: WHISKEY_GULCH_1_XRMI_29AUG21_7710- 10233_XRMI_Beds_Fractures_Dips.las 35946ED Digital Data DF 11/12/20217710 10230 Electronic Data Set, Filename: WHISKEY_GULCH_1_XRMI_29AUG21_7710- 10233_XRMI_FRACTURE_FREQUENCY.las 35946ED Digital Data DF 11/12/2021 Interpretation files not required under 20 AAC 25.071, will not be released. M.Guhl 2/23/2024 35946ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_29AUG21_7710- 10233_XRMI_Beds_Fractures_Dips.csv 35946ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_29AUG21_PROCE SSED_XRMI_IMAGE_7710-10233.dlis 35946ED Digital Data Friday, February 23, 2024AOGCC Page 9 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_29AUG21_PROCE SSED_XRMI_IMAGE_7710-10233.ver 35946ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_29AUG21_RAW_X RMI_IMAGE_7710-10233.dlis 35946ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_29AUG21_RAW_X RMI_IMAGE_7710-10233.ver 35946ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_29AUG21_XRMI_S TATIC_DYNAMIC_IMAGE_7710- 10233_1to20.pdf 35946ED Digital Data DF 11/12/2021 Electronic File: WHISKEY_GULCH_1_XRMI_29AUG21_XRMI_S TATIC_DYNAMIC_IMAGE_7710-10233_1to20.tif 35946ED Digital Data DF 1/18/20224627 4350 Electronic Data Set, Filename: WG-01 CORRELATION LOG T-48 20' PERF.las 36242ED Digital Data DF 1/18/20226330 5954 Electronic Data Set, Filename: WG-01 CORRELATION LOG WITH 12' PERF.las 36242ED Digital Data DF 1/18/20224963 4675 Electronic Data Set, Filename: WG-01 CORRELATION LOG WITH 6.25INCH CBP.las 36242ED Digital Data DF 1/18/20226347 6039 Electronic Data Set, Filename: WG-01 CORRELATION LOG WITH GUN #2.las 36242ED Digital Data DF 1/18/20226315 5982 Electronic Data Set, Filename: WG-01 CORRELATION LOG WITH GUN #3.las 36242ED Digital Data DF 1/18/20223762 3487 Electronic Data Set, Filename: WG-01 CORRELATION WITH CBP-2.las 36242ED Digital Data DF 1/18/2022-17 6362 Electronic Data Set, Filename: WG-01 GPT 12- 27-21 BEFORE 24' PERF.las 36242ED Digital Data DF 1/18/2022-38 6818 Electronic Data Set, Filename: WG-01 GPT AFTER FLOW.las 36242ED Digital Data DF 1/18/2022338 7380 Electronic Data Set, Filename: WG-01 GPT.las36242EDDigital Data DF 1/18/20224680 4428 Electronic Data Set, Filename: WG-01 GUN #2 COR LOG LOWER T-48 20' PERF.las 36242ED Digital Data DF 1/18/20225990 6246 Electronic Data Set, Filename: WG-01 LOG ACROSS 24' PERF.las 36242ED Digital Data Friday, February 23, 2024AOGCC Page 10 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 1/18/2022 Electronic File: WG-01 CORRELATION LOG T- 48 20' PERF.pdf 36242ED Digital Data DF 1/18/2022 Electronic File: WG-01 CORRELATION LOG WITH 12' PERF.pdf 36242ED Digital Data DF 1/18/2022 Electronic File: WG-01 CORRELATION LOG WITH 6.25INCH CBP.pdf 36242ED Digital Data DF 1/18/2022 Electronic File: WG-01 CORRELATION LOG WITH GUN #2.pdf 36242ED Digital Data DF 1/18/2022 Electronic File: WG-01 CORRELATION LOG WITH GUN #3.pdf 36242ED Digital Data DF 1/18/2022 Electronic File: WG-01 CORRELATION WITH CBP-2.pdf 36242ED Digital Data DF 1/18/2022 Electronic File: WG-01 FINAL GPT LOG .pdf36242EDDigital Data DF 1/18/2022 Electronic File: WG-01 FINAL PLUG AND PERF LOG .pdf 36242ED Digital Data DF 1/18/2022 Electronic File: WG-01 GPT 12-27-21 BEFORE 24' PERF.pdf 36242ED Digital Data DF 1/18/2022 Electronic File: WG-01 GPT.pdf36242EDDigital Data DF 1/18/2022 Electronic File: WG-01 GUN #2 COR LOG LOWER T-48 20' PERF.pdf 36242ED Digital Data DF 1/18/2022 Electronic File: WG-01 LOG ACROSS 24' PERF.pdf 36242ED Digital Data DF 2/4/20222400 3634 Electronic Data Set, Filename: WG 01 GPT DOWN PASS 1-5-22.las 36310ED Digital Data DF 2/4/20223639 2395 Electronic Data Set, Filename: WG 01 GPT UP PASS 1-5-22.las 36310ED Digital Data DF 2/4/20223437 3168 Electronic Data Set, Filename: WG-01 AFTER PERF T-18 SAND.las 36310ED Digital Data DF 2/4/20223420 3110 Electronic Data Set, Filename: WG-01 CORRELATION T-18 SAND.las 36310ED Digital Data DF 2/4/20220 3636 Electronic Data Set, Filename: WG-01 GPT 1-5- 22.las 36310ED Digital Data DF 2/4/2022 Electronic File: WG 01 GPT DOWN PASS 1-5- 22.pdf 36310ED Digital Data DF 2/4/2022 Electronic File: WG 01 GPT UP PASS 1-5-22.pdf36310EDDigital Data Friday, February 23, 2024AOGCC Page 11 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 2/4/2022 Electronic File: WG-01 AFTER PERF T-18 SAND.pdf 36310ED Digital Data DF 2/4/2022 Electronic File: WG-01 CORRELATION T-18 SAND.pdf 36310ED Digital Data DF 2/4/2022 Electronic File: WG-01 GPT 1-5-22.pdf36310EDDigital Data DF 2/4/2022 Electronic File: WHISKEY GULCH 01 GPT FINAL.pdf 36310ED Digital Data DF 2/4/2022 Electronic File: WHISKEY GULCH 01 PERF FINAL.pdf 36310ED Digital Data DF 2/4/20223502 3224 Electronic Data Set, Filename: WG-01 CORRELATION GUN 1.las 36311ED Digital Data DF 2/4/20220 9740 Electronic Data Set, Filename: WG-01 GPT FB 1.las 36311ED Digital Data DF 2/4/20223374 3102 Electronic Data Set, Filename: WG-01 GPT FB 2.las 36311ED Digital Data DF 2/4/20220 4551 Electronic Data Set, Filename: WG-01 GPT FB 3.las 36311ED Digital Data DF 2/4/20220 2111 Electronic Data Set, Filename: WG-01 GPT FB 4.las 36311ED Digital Data DF 2/4/20223374 3100 Electronic Data Set, Filename: WG-01 GPT FB 5.las 36311ED Digital Data DF 2/4/20223374 3092 Electronic Data Set, Filename: WG-01 GPT FB 6.las 36311ED Digital Data DF 2/4/20220 2818 Electronic Data Set, Filename: WG-01 GPT FB 7.las 36311ED Digital Data DF 2/4/20223374 3023 Electronic Data Set, Filename: WG-01 GPT FB 8.las 36311ED Digital Data DF 2/4/2022-30 1390 Electronic Data Set, Filename: WG-01 GPT LOG FL 1150.las 36311ED Digital Data DF 2/4/20223148 3464 Electronic Data Set, Filename: WG-01 GPT LOG PF 3375.las 36311ED Digital Data DF 2/4/2022 Electronic File: WG-01 CORRELATION GUN 1.pdf 36311ED Digital Data DF 2/4/2022 Electronic File: WG-01 FLOW - FLUID LEVEL FINAL.pdf 36311ED Digital Data DF 2/4/2022 Electronic File: WG-01 GPT FB 1.pdf36311EDDigital Data Friday, February 23, 2024AOGCC Page 12 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No DF 2/4/2022 Electronic File: WG-01 GPT FB 2.pdf36311EDDigital Data DF 2/4/2022 Electronic File: WG-01 GPT FB 3.pdf36311EDDigital Data DF 2/4/2022 Electronic File: WG-01 GPT FB 4.pdf36311EDDigital Data DF 2/4/2022 Electronic File: WG-01 GPT FB 5.pdf36311EDDigital Data DF 2/4/2022 Electronic File: WG-01 GPT FB 6.pdf36311EDDigital Data DF 2/4/2022 Electronic File: WG-01 GPT FB 7.pdf36311EDDigital Data DF 2/4/2022 Electronic File: WG-01 GPT FB 8.pdf36311EDDigital Data DF 2/4/2022 Electronic File: WG-01 GPT FINAL.pdf36311EDDigital Data DF 2/4/2022 Electronic File: WG-01 GPT LOG FL 1150.pdf36311EDDigital Data DF 2/4/2022 Electronic File: WG-01 GPT LOG PF 3375.pdf36311EDDigital Data DF 2/4/2022 Electronic File: WG-01 PERF FINAL.pdf36311EDDigital Data DF 3/4/20222850 2638 Electronic Data Set, Filename: WG-01 COM. PLUG CORRELATION 2800FT.las 36385ED Digital Data DF 3/4/20223304 3046 Electronic Data Set, Filename: WG-01 COM. PLUG CORRELATION PART 2.las 36385ED Digital Data DF 3/4/20223305 3042 Electronic Data Set, Filename: WG-01 COM. PLUG CORRELATION.las 36385ED Digital Data DF 3/4/20222206 1936 Electronic Data Set, Filename: WG-01 CORRELATION LOG WITH 14' GUN - T-10.las 36385ED Digital Data DF 3/4/20222998 2745 Electronic Data Set, Filename: WG-01 CORRELATION LOG WITH 20' GUN - T-14A.las 36385ED Digital Data DF 3/4/20222130 1950 Electronic Data Set, Filename: WG-01 CORRELATION WITH GAUGE HGR.las 36385ED Digital Data DF 3/4/20220 73498 Electronic Data Set, Filename: WG-01 GPT MONITOR WHILE FLOW.las 36385ED Digital Data DF 3/4/2022 Electronic File: WG-01 COM. PLUG CORRELATION 2800FT.pdf 36385ED Digital Data DF 3/4/2022 Electronic File: WG-01 COM. PLUG CORRELATION PART 2.pdf 36385ED Digital Data DF 3/4/2022 Electronic File: WG-01 COM. PLUG CORRELATION.pdf 36385ED Digital Data DF 3/4/2022 Electronic File: WG-01 CORRELATION LOG WITH 14' GUN - T-10.pdf 36385ED Digital Data Friday, February 23, 2024AOGCC Page 13 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No Well Cores/Samples Information: ReceivedStart Stop Comments Total Boxes Sample Set NumberName Interval DF 3/4/2022 Electronic File: WG-01 CORRELATION LOG WITH 20' GUN - T-14A.pdf 36385ED Digital Data DF 3/4/2022 Electronic File: WG-01 CORRELATION WITH GAUGE HGR.pdf 36385ED Digital Data DF 3/4/2022 Electronic File: WG-01 FLOW BACK T-18 FINAL.pdf 36385ED Digital Data DF 3/4/2022 Electronic File: WG-01 FLUID BEFORE SET PLUG.pdf 36385ED Digital Data DF 3/4/2022 Electronic File: WG-01 GPT MONITOR WHILE FLOW.pdf 36385ED Digital Data DF 3/4/2022 Electronic File: WG-01 PLUG PERF T-14 FINAL.pdf 36385ED Digital Data DF 3/4/2022 Electronic File: WG-01 PLUG-PERF T-10 SAND FINAL.pdf 36385ED Digital Data DF 3/4/2022 Electronic File: WG-01GPT FLUID FOR LAST PLUG FINAL.pdf 36385ED Digital Data DF 1/20/2023 Electronic File: 202105324 - WG1 - Routine Final Report - 3-Jan-2023.pdf 37455ED Digital Data DF 1/20/2023 Electronic File: 2105324_Whiskey Gulch 1_RCAL (Batch Cleaned)_25-Feb-22.xlsx 37455ED Digital Data DF 1/20/2023 Electronic File: 2105324_Whiskey Gulch 1_RCAL (Flow Thru Cleaned)_11-Feb-22.xlsx 37455ED Digital Data DF 1/20/2023 Electronic File: 2105324_Whiskey Gulch 1_RCAL Final_16-Dec-2021.xlsx 37455ED Digital Data 9/9/2021120 10271 71781Cuttings Sidewall Core: Routine Core Analysis Core Description Core Photos Friday, February 23, 2024AOGCC Page 14 of 15 DATA SUBMITTAL COMPLIANCE REPORT API No.50-231-20079-00-00Well Name/No.WHISKEY GULCH 1 Completion Status 1-GASCompletion Date 12/22/2021 Permit to Drill 2210460 Operator Hilcorp Alaska, LLC MD 10271 TVD 9332 Current Status 1-GAS 2/23/2024 UIC No INFORMATION RECEIVED Completion Report Production Test Information Geologic Markers/Tops Y Y / NA Y Comments: Compliance Reviewed By:Date: Mud Logs, Image Files, Digital Data Composite Logs, Image, Data Files Cuttings Samples Y / NA Y Y / NA Directional / Inclination Data Mechanical Integrity Test Information Daily Operations Summary Y Y / NA Y Core Chips Core Photographs Laboratory Analyses Y / NA Y / NA Y / NA COMPLIANCE HISTORY Date CommentsDescription Completion Date: 12/22/2021 Release Date: 1/22/2024 Friday, February 23, 2024AOGCC Page 15 of 15 M.Guhl 2/23/2024 From:Heusser, Heather A (DNR) To:Guhl, Meredith D (OGC) Cc:Morgan, Kirk A (DNR) Subject:RE: Whiskey Gulch 1, PTD 221-046, Extended Confidentiality requested? Date:Wednesday, February 21, 2024 11:03:18 AM Hi Meredith, The DOG Director’s Office confirmed we have not received an extended confidentiality request for Whiskey Gulch 1. Happy releasing! Heather Ann Heusser Natural Resource Specialist IV State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage AK 99501-3560 heather.heusser@alaska.gov From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Wednesday, February 7, 2024 10:55 AM To: Heusser, Heather A (DNR) <heather.heusser@alaska.gov> Subject: Whiskey Gulch 1, PTD 221-046, Extended Confidentiality requested? Hello Heather, Hilcorp Alaska’s Whiskey Gulch 1 exploratory well, PTD 221-046, API 50-231-20079-00-00, was due for release from confidentiality after January 22, 2024. Has Hilcorp requested extended confidentiality for this well? Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FI11].N1 IAL FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 2. Facility Name 3. Held 4. Operator 5. MonthlYearcl Disposition 231000006 Whiskey Gulch Whiskey Gulch Hflcorp Alaska TC I January-24 Disposition Volume MCF 20. For production from multiple pock, list contribution ofeach pool as a percent of Total Volume. 6. Sold Pool Name Pool Code Percent Whiskey Gulch 94D50D 100 00 7_ Reinjected 8_ Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see inst- ) 10_ Pilot and Purge 11_ Assist Gas 12_ Fuel gas used in lease operations_ 13. Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) MCF Lease Use 15. NGL Gas Equivalent MCF Conservati 16_ Purchased gas MCF Waste 17_ Transferred from: Reviewed by COMMISSIONER 18. Transferred to: (Express as a negative#) Comm_ Comm_ 19_ Remarks_ I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? `� Date of Revision: Title: Production Analyst Authorized Name and Digital Signature with date_ ugraiN sqn Vryma Contact Phone= .. 7132892658 Note: All volumes must 6e corrected to pressure Cyndi oN h�S a of 14.65 psi& and to a temperature of 60' F. auynnta et Huynh (838) °ate CyL i2n 13St5l- Authority 20AAC 25.235. oeoo Contact Email: chu nh hilco .com Form 10422 Revd 0AUM 20 AAG 25235 Submit in PDF formal to wgcc.reporting@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25.230 F Cll�IDENTIAL Form 10-005 Rev. 1012021 20 AAC 25235 Submil in PDF format to aegcc.reporbng@alaska.gov CONFIDENTIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 2. Facility Name 3. Field lWhiskey 4. Operator 5. MonthNear of Disposition 231000006 Wh iskey Gulch Gulch Hilcorp Alaska.LLC I December-23 Disposition Volume MCF 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume. 6. Sold Pool Name Pool Code Percent Whiskey Gulch 940500 100.00% 7. Reinjected S. Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas 12. Fuel gas used in lease operations. Official Use 13. Other (see instructions) Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6.13) Lease Use MCF 15. NGL Gas Equivalent Gonservati MCF 16. Purchased gas Waste I MCF Reviewed by: 17. Transferred from: COMMISSIONER Comm. Corilr, 18. Transferred to: (Express as a negative #) 19. Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Date of Revision: Title: Production Analyst Authorized Name and Digital Signature with date: Contact Phone: 713.289.2658 Note, All volumes must be corrected to pressure Cyndi oWynn ysigned �' Cyndi of 14.65 psia and to a temperature of 60' F. n"`m-"jriHiryih"' HUynh (838)zozami is2sn- MW Contact Email: chu nh hilcor .cam Authority20AAC25.235. Form 10422 Revised 0412020 20 AAC 25.235 Submit in PDF format to aogcc.reportmg@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25.230 C.ONI� Il)ENTIAL Farm 10-005 Rev. 1072021 20 AAC 25235 Submil in PDF format to aogcc.reportng@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION IAL (CANFIDEANT 29 FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 2. Facility Name 3. Field lWhiskey 4. Operator 5. MonthNear of Disposition 231000006 Wh iskey Gulch Gulch Hilcorp Alaska.LLC I November-23 Disposition Volume MCF 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume. 6. Sold Pool Name Pool Code Percent Whiskey Gulch 940500 100.00% 7. Reinjected S. Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas 12. Fuel gas used in lease operations. Official Use 13. Other (see instructions) Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6.13) Lease Use MCF 15. NGL Gas Equivalent Gonservati MCF 16. Purchased gas Waste I MCF Reviewed by: 17. Transferred from: COMMISSIONER Comm. Corilr, 18. Transferred to: (Express as a negative #) 19. Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Date of Revision: Title: Production Analyst Authorized Name and Digital Signature with date: Contact Phone: 713.289.2658 Note, All volumes must be corrected to pressure Cynd1 oHUYM yM �� of 14.65 psia and to a temperature of 60' F. Huynh (838) � �-� Contact Email: hilcor Authority20AAC 25.235. 06Wrmza.iz.isos�a:aa- chu nh .cam Form 10422 Revised 0412020 20 AAC 25.235 Submit in PDF format to aogcc.reportmg@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25.230 (OMNFIDE\TIAL Form 10-005 Rev. 1012021 20 AAC 25235 Submil in PDF format to aegcc.reportng@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 2. Facility Name lWhiskey 3. Field 4. Operator 5. MonthNear of Disposition 231000006 Gulch lWhiskey Gulch I Hilcorip Alaska.LLC I October-23 Disposition Volume MCF 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume. 6. Sold Pool Name Pool Code Percent hiskey Gulch 940500 100.00% 7. Reinjected S. Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Assist Gas 12. Fuel gas used in lease operations. Official Use 13. Other (see instructions) uthorization Safety MCF 14. TOTAL VOLUME (ITEMS 6.13) Lease Use MCF 15. NGL Gas Equivalent Gonservati MCF 16. Purchased gas Waste MCF eviewed by: 17. Transferred from: COMMISSIONER 18. Transferred to: (Express as a negative #) omm. Corilr, 19. Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Date of Revision: Title: Production Analyst Authorized Name and Digital Signature with date: Contact Phone: 713.289.2658 Note, All volumes must be corrected to pressure DgitalMi Cyndi Hymnye3aj "�� of 14.65 psia and to a temperature of 60' F. oN�r4Kq d�nu�nnte3e7 Huynh (838) 0��1120 141703- WWI Contact Email: chu nh hilcor .cam Authority20 AAC 25.235. Form 10422 Revised 0412020 20 AAC 25.235 Submit in PDF format to aogcc.reportmg@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25.230 ECANFIDEANTIAL Form 10-005 Rev. 1012021 20 AAC 25235 Submil in PDF format to aegcc.reporhng@alaska.gov (3ONTIl)I,\ FIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. MonthlYear GIDisposition 231000006 Whiskey Gulch Whiskey Gulch Hflcorp Alaska TC I September-23 Disposition Volume MCF 20. For production from mudiple pock, list contribution ofeach pool as a percent of Total Volume. 6. Sold Pool Name Poal Code Percent Whiskey Gulch 94D50D 100 00 7_ Reinjected 8_ Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see inst- ) 10_ Pilatand Purge 11_ Assist Gas 12_ Fuel gas used in lease operations_ 13 Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) MCF Lease Use 15. NGL Gas Equivalent MCF Conservati 16_ Purchased gas MCF Waste 17_ Transferred from: Reviewed by COMMISSIONER 18. Transferred to: (Express as a negative#) Comm JeCorm_ 19_ Remarks_ I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? `� Date of Revision: Title: Production Analyst Authorized Name and Digital Signature with date_ oly �mr by cyrai Contact Phone = 713.289.2658 Note: All volumes must be corrected to pressure Cyndi oigiraiN h(830) of 14.65 psi& and to a temperature of 60' F. luynb (aael Date 21123.10 2012.43.19- HU nh 838Contact Email: chu nh hilco .com Authority 20 AAC 25.235. Form 10422 Revised 04r2020 20 AAG 25235 Submit in PDF Format to wgcc.reporting@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25.23D CONFIDENTIAL Name of Operate, Fieldand PaaL Whiskey Gulch, Whiskey Gulch, UrdeRned Muni and Year HILCORP ALASKA. LLC September2023 1. Well Na. 2 API No. 3. Type 4. Field & 5. Method 6. Days in Opec 7. Avg. FLIP DAILYAVG. PRODUCTION TOTAL MONTHLY PRODUCTION 50- )ON -XXX)OFXX-XX (see Pool (see psg(see B. OIL 9_ 10_GAS 11.OIL 12_WATER 13_GAS instrud.J Cade instruct) instruct.) (FIBL) WATER(BBL) (Bill(nBL) I (BBL) (BBL) Whiskey Gulch 01 50-231-20079-00-00 2 9g0500 8 8 11 0 0 0 0 0 0 I hereby certily that the foregoing is true and correct to the best of my knowledge. 14. Tito Production Analyst Date Of Revision? Revision Authorized Name and Digital Sgnature with date_ Cardaetphone 7132892658 Di holy signed by Cyndl Cyndi Huynh tB9) DIN li Hn nh Hu nh 838 Data 2D23.iollaz1.44 - T-_ 06dt CamactEmaiE chuvnhCa�hflcorD.com Farm 10-005 Rev_ 1012021 20 AAC 25236 Subm t in PDT format teaagcc repoZigl goy (",ONl+ 17W1%'I'IDAIA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. MonthlYear GIDisposition 231000006 Whiskey Gulch Whiskey Gulch Hflcorp AJaska_LLC Augusl623 Disposition Volume MCF 20. For production from mudrple pock, list contribdm ofeach pool as a percent of Total Volume. 6. Sold Pool Name Pool Code Percent Whiskey Gulch 94D50D 100 00 7_ Reinjected 8_ Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see inst- ) 10_ Pilot and Purge 11_ Assist Gas 12_ Fuel gas used in lease operations_ 13 Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) MCF Lease Use 15. NGL Gas Equivalent MCF Conservati 16_ Purchased gas MCF Waste 17_ Transferred from: Reviewed by COMMISSIONER 18. Transferred to: (Express as a negative#) Comm 1COMM_ 19_ Remarks_ I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? `� Date of Revision: Title: Production Analyst Authorized Name and Digital Signature with date_ RgWy&WW by cyWi C Contact Phone = 713.2892658 Note: All volumes must be corrected to pressure y ndi Huynb(etei of 14.65 psi& and to a temperature of 60' F. DI m�yrxii 1, t8le) : Huynh (838) Dale zozaomao osm9 ax- Authority 20 4Ac 25.235. msmv Contact Email: chu nh hilco .com Form 10422 Revised 04r2020 20 AAG 25235 Submit in PDF Format to wgcc.reporting@alaska.gov ■ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25.230 CONFIDENTIAL] Name of Operaitor Field and Pod. Whiskey Gulch, Whiskey Gulch, Undefined Month and Year HILCORP ALASKA, TO August2❑23 1. Well No. 2. API No. 3. Type 4. Feld & 5. Method 6. Days in Oper_ 7. Avg. FTP DAILY AVG. PRODUCTION TOTAL MONTHLY PRODUCTION 5BXXX-XXIO❑(-XX-XX (see Poal (see I prig (see B OIL 9_ 10_ GAS 11 OIL 12_ WATER 13 GAS insWal.j Cade instruct.} instruct.) (BBL) I WATER(BBL) I (BBL) (BBL) I (BBL) I (BBL) Whiskey Gulch 0l 1 50-231-20079-0000 1 2 940500 1 a 1 01 111 01 01 ❑ 0 ❑ ❑ 1 hereby certify, that the toregaing is true and correct Lo the best of my knowledge. 14_ TitleProduction Analyst 1 Date of ReYi51W17 ReYi510f1_ AuthDreed Name and Dgital Sgnatum with date_ DgilalH all byCyndi Cyndi Hujmh(836) DW ocC)ndi "111) Contact Phone' 7132892658 Huynh (838) ta=IMM1384737- TGTAL Contact Emil: a chuvnhlcDhilcorD.com Farm 10-005 Rev_ 10Rf121 20 AAC 25.236 Sul in PDF format to aagcc urportingQalaska goy C.ONl{ IDEAN'1 IAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 2. Facility Name 3. Hold 4. Operator 5. Monthtyear ar Dispositcn 231000006 Whiskey Gulch Whiskey Gulch Hflcorp Alaska LLC July-23 Disposition Volume MCF 20. For production from multiple pock, list contribution ofeach pool as a percent of Total Volume. 6. Sold Pool Name Poal Code Percent Whiskey Gulch 94D50D 100 00 7_ Reinjected 8_ Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see inst-) 10_ Pilctand Purge 11_ Assist Gas 12_ Fuel gas used in lease operations_ 13 Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) MCF Lease Use 15. NGL Gas Equivalent MCF Conservati 16_ Purchased gas MCF Waste 17_ Transferred from: Reviewed by COMMISSIONER 18. Transferred to: (Express as a negative #) Comm lComm_ 19_ Remarks_ I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? Date of Revision: Title: Production Analyst Authorized Name and Digital Signature with date_ oi9ilAy sib by cymi Cynd Contact Phone = 713.289 2658 Note: All volumes must be corrected to pressure I rlvynn(w tare' ' "I"' of 14.65 psis and to a temperature of 60' F. Huynh (838)n5 "1W1921[UM- Authority 20 AAC 25.236. Contact Email: chu nh hilco .com Form 10422 Revisad 04r2020 20 AAG 25235 Submit in PDF lonnal to aogcc.repodingnalaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25.230 (I()N I1)EATIAL HILCORP ALASKA, TO Ju172023 1. Well No. 2. API No. 3. Type 4. Feld &1 5. Method 1 6. Days in OpeL 7. Avg. FTP DAILY AVG. PRODUCTION TOTAL MONTHLY PRODUCTION 5a)U9FX7❑IX%-X%-7IX (see Poal (see prig (see BOIL 9_ 11)_GAS iLOIL 12 WATER 13_GAS in.Wct.) Cade instruct.} instruct.) (BBL} WATER(BBL) (BBL) (66L} (BBL} (BBL( Whiskey Gu1ch01 50-231-2W79-0D-0❑ 2 94❑5❑❑ a D 0 0 0 ❑ 0 nl ❑ Hoh e) °Dy� Cyndi Hunh //838 D" cn 111 Fn l(�Tfl, Y l ) Data 2023.00.1618:51- 0500' Revision? �� Date of Revision_ Contact Phoney 713 289 2658 Contact Emai.: chOVrtl[ 14_ Farm IIIAM Rev_ 10Rf121 20 AAC 25.236 Suhm9 in PD F farm at to aogcc repertil lacka gov CONFIDENTIAL E - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 2. Facility Name 3. Hold 4. Operator 5. Monthlyear al Disposition 231000006 Whiskey Gulch Whiskey Gulch Hflcorp AlaskaJTC Juna23 Disposition Volume MCF 20. For produchron from mudrple pock, list contribution ofeach pool as a percent of Total Volume. 6. Sold Pool Name Poal Code Percent Whiskey Gulch 94D50D 100 00 7_ Reinjected 8_ Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see inst-) 10_ Pilctand Purge 11_ Assist Gas 12_ Fuel gas used in lease operations_ 13 Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) MCF Lease Use 15. NGL Gas Equivalent MCF Conservati 16_ Purchased gas MCF Waste 17_ Transferred from: Reviewed by COMMISSIONER 18. Transferred to: (Express as a negative#) Comm 1COMM_ 19_ Remarks_ I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? `� Date of Revision: Title: Production Analyst Authorized Name and Digital Signature with date_ Digaaty �m by C)nbi Cyndi Contact Phone = 713.289 2658 Note: All volumes must be corrected to pressure fwym (ava) �_ mx�i Hmyr�n (a3s) off 4.65 psis and to a temperature of 60° F. H u yn h {8 38) n� 2ox3oi 1T 1340 5e - Authority 20 AAC 25.235. 05W Contact Email: chu nh hilco .com Form 10422 Revisad 04r2020 20 AAG 25235 Submit in PDF format to wgcc.reporting@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT M MC 25 2M NaneaOpmame Fm and Loud: Wlnxey GulN, Whir" Gul Unnamed! Wi am year HILCORPA M. LLC June= 1. Well 2APIND 3. Type O. Field 5. Method 6. Days in Opm. ]Avg. FTP OAILYAVG. PRODUCTION TOTAL Most PRODMAON W-X%%-X%%T2(-MX (see BPmI (see psg(see 8. OIL 9. 10. GAS 11. OIL 12_Wi 13. GAS nsWc1.) Food Instruct) immuct( (BBT WAR( (BBL) (BBL( (BBL) (BBL) Wbn"Guici MLB1-21g7g 2 W500 8 0 0 0 0 0 0 0 0 I hereby ceMy that Me foregoing a Due and m d btle Most of my knowl. TNe: Peel Analyst Date Of Res islOn9 14_ AmMonzed Name and ogilal SgnaWre ash Male: Rev61nrt Gol Pbme- 7132892858 TOTAL c d i-- chu� 1 Fmm 10405 Rev_ 102IM1 20 PAC 25.235 Submit in PDF forms to seems repomm@alasFa gov CONFIDENTIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 2. Facility Name 3. Hold 4. Operator 5. Monthlyear at Disposition 231000006 Whiskey Gulch Whiskey Gulch Hflcorp Alaska TC May-23 Disposition Volume MCF 20. For produrdron from multiple pock, list contribution ofeach pool as a percent of Total Volume. 6. Sold Pool Name Poal Code Percent Whiskey Gulch 94D50D 100 00 7_ Reinjected 8_ Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see inst- ) 10_ Pilctand Purge 11_ Assist Gas 12_ Fuel gas used in lease operations_ 13 Other(see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) Lease Use MCF 15. NGL Gas Equivalent Conservati MCF 16_ Purchased gas Waste MCF 17_ Tmnsfened from: Reviewed by COMMISSIONER 18. Transferred to: (Express as a negative #) Commin jCMm_ 19_ Remarkst I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? `� Date of Revision: Title: Production Analyst Authorized Name and Digital Signature with date_ Cyndi Hu h Dynally �m by Clma Contact Phone = 713.289.2658 Note: All volumes must be corrected to pressure Tynd i Huynh (s3e) of 14.65 psis and to a temperature of 60' F. DN`.xVr HyM(M] HU nh 838 0 2@3WX19°1z - Contact Email: chu nh hilco .com Authority 20 AAC 25.235. Form 10422 Revised 04r2020 20 AAG 25235 Submit in PDF Formal to wgcc.reporting@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25.230 ('30Nl'IDEANI IAA HILCORP ALASKA, LLC Month and Year: May-23 1. Well No. 2 API No. 3. Type 4. Field &1 5. Method 1 6. Days in Oper. 7. Avg. FTP DAILYAVG. PRODUCTION TOTAL MONTHLY PRODUCTION 50-)=XXX)OFXX-XX (sne Paol (see I sg(see 8.01E 9_ 1D_GAS 11.OIL 12_WATLR 13_GAS instrud.J Cade I instruct) inskuct.) (BBL) WATER(BBL) (BBL) (BBL) (BBL) (BBL) Whiskey Gulch Ol 50-231-20079-00-00 1 2 940500 1 B I0 111 01 01 01 0 01 0 Digitally ygnpd by ()ndl Cyndi oN ci,Cyndi Huynn(ale) Huynh (838) a �=B6201941M- Revision? RevisionDate of _ Cantaet Phone_ 7132892658 CanlactEmaih_ chuvnhc hilcc -; :T- Farm 10-005 1_ 1012021 20 AAC 25236 Submit in PDF format to aogcc repoding&alaska gm (ION i Il)EATIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 2. Facility Name 3. Field 4. Operator 5. MonifllYearof Disposition 231000006 Whiskey Gulch Whiskey Gulch Hflcorp Alaska_LLC April-23 Disposition Volume MCF 20. For production from mudrple pock, list contribution ofeach pool as a percent of Total Volume. 6. Sold Pool Name Pool Code Percent Whiskey Gulch 94D50D 100 00 7_ Reinjected 8_ Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see inst- ) 10_ Pilot and Purge 11_ Assist Gas 12_ Fuel gas used in lease operations_ 13 Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) MCF Lease Use 15. NGL Gas Equivalent MCF Conservati 16_ Purchased gas MCF Waste 17_ Transferred from: Reviewed by COMMISSIONER 18. Transferred to: (Express as a negative #) Commin lemm_ 19_ Remarkst I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? `� Date of Revision: Title: Production Analyst Authorized Name and Digital Signature with date_ Cyndi Huynh Ugg.11y.Igged by crmi Contact Phone = 713.289.2658 Note: All volumes must be corrected to pressure Cyndi Huynh Huynh reae, of 14.65 psis and to a temperature of 60' F. ❑.1msvmdimuymnis g, Authority 20 AAC 25.235. (838) osorvsgza.osds.a�rsa Contact Email: chu nh hilco .com Form 10422 Revised 04r2020 20 AAG 25235 Submit in PDF Format to wgcc.reporting@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25.230 C.ONI{ Il)EATIAL HILCORP ALASKA, LLC Month and Year: Apr-23 1. Well No. 2 API No. 3. Type 4. Field &1 5. Method 1 6. Days in Oper. 7. Avg. FTP DAILYAVG. PRODUCTION TOTAL MONTHLY PRODUCTION 50-70IX-XXX)OFXX-XX (see Paol (see I sg(see 8.01E 9_ 1n_GAS 11.OIL 12_WATLR 13_GAS instrud.J Cade I inetmd) inskoct.) (BBL) WATER(BBL) (BBL) (BBL) (BBL) (BBL) Whiskey Gulch0l 50-231-20079-00-00 1 2 940500 1 B I0 111 01 01 01 0 01 0 o§aviry vnsm W Ly,�al Cyndi Huynh p d mhtaM) (838) o ta2023P519133211- Revision? RevisionDate of _ Cantant Phone_ 7132892658 CamactEmaih_ chuvnhc hilcc - :T- Farm 10-005 1_ 1012021 20 AAC 25236 Submit in PDF format k aogm repodingQalaska gm C'ONF IDENTIAL ALASKA UII_ ANU UAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 2. Facility Name 3. Hold 4. Operator 5. Monthlyear al Disposition 231000006 Whiskey Gulch Whiskey Gulch Hflcorp AlaskaJTC March-23 Disposition Volume MCF 20. For produrdron from mudrple pock, list contribution ofeach pool as a percent of Total Volume. 6. Sold Pool Name Poal Code Percent Whiskey Gulch 94D50D 100 00 7_ Reinjected 8_ Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see inst-) 10_ Pilctand Purge 11_ Assist Gas 12_ Fuel gas used in lease operations_ 13 Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) MCF Lease Use 15. NGL Gas Equivalent MCF Conservati 16_ Purchased gas MCF Waste 17_ Transferred from: Reviewed by COMMISSIONER 18. Transferred to: (Express as a negative#) Comm 1COMM_ 19_ Remarks_ I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? `� Date of Revision: Title: Production Analyst Authorized Name and Digital Signature with date_ Jennifer Dove o;�m�y9une mr� Jennifer Contact Phone 713.289.2809 Note: All volumes must be corrected to pressure hl of 14.65 psra and to a temperature of 60' F. Doge (5388) ON. HnWLb �'+ Authority 20 AAC 25.235. oa�svrxw,m "�511-0�0' Contact Email: ionntler.dove hilcor .Coro Form 10422 Revd 0412020 20 AAG 25235 Submit in PDF format to wgcc.reporting@alaska.gov ■ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION MONTHLY PRODUCTION F 20 AAC 25.23D 40'.O TFIDENTIAL Name of Opemkrr 0 HILCORP RI_ASKA, LLC Month and Year: Mar-23 1. Well No. 2 API No. 3. Type 4. Field & 5. Method 6. Days in Oper. 7. Avg. FLIPDAILY AVG. PRODUCTION TOTAL MONTHLY PRODUCTION 50-)=XXX)OFXX-XX (see Pool (see psg(see 8.01E 9_ 1D_GAS 11.OIL 12_WATER 13_GAS instruct.) Cade instruct( instruct.) (BBL) WATER(BBL) (BBL) (BBL) (BBL) I (BBL) Whiskey Gulch 01 50-231-20074-00Oil 1 2 AO500 1 0 1 01 ul 01 01 01 01 01 0 I hereby mrlily that the humgoing s true and wnrect to the best of my knowledge. 14_ TAIeProduction Analyst Revision? Date Of Revision Authorized Name and Digital SgnaWre with date_ Jennifer by "��ni— D,"*-` on'ati""rv�°°'e (steal' Dove (5388),�p„�,,,, Contact Phone_ 7132892889 ConlactEmaiE jennifer.dovefahilcoro.com Farm 10-005 Rev_ 10f2021 20 AAC 25 235 Submit in PDT format to aogcc mpoding&alaska gm C.ONI�IDE4ANTIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1_ Faulity Number 2 Facility Name 3. Field 4. Operator 5_ MonthlYearof Disposition 231000006 Whisk Gulch Whiskey Gulch Hilro AlaskalLC February-23 Disposition Volume MCF 20. For production from multiple pools, lisf cons ifwtion of each pool as a percent of Total Volume. 6_ Sold Pool Name Pool Code Percent Whiskey Gulch 940500 10000% 7_ Reinjected 8_ Flared or vented 1 hour or less 9_ Flared or vented more than 1 hour (see instr.} 10. Pilot and Purge 11_ Assist Gas 12. Fuel gas used in lease operations. 13. Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) Lease Use MCF 15_ NGL Gas Equivalent Conservati MCF 16_ Purchased gas Waste MCF 17. Transferred from: Reviewed by COMMISSIONER 18. Transferred to: (Express as a negative fit) Comm_ Comm_ 19_ Remarks_ I hereby certify that the foregoing is true and correct to the hest of my knowledge_ Revision? Date of Revision' Tdle_ Production Analyst Authorized Name and Digital Signature with date_ Jennifer Dove Jennifer �lr ar.rem,e, ow.` Contact Phone = 713 289288g Note: All volumes must be corrected to pressure re s All v l umpsla of and to a temperature of F. on or�mr�a owe ISrssa1. Dove (5388) am„ A uthorify 20 AAC 25.235. Contact Email: lennifer.dovetalhilcorp.com Pam 10422 Revised 10f2021 20 PAC 25.235 Submit in P DF format to aogtt. mportingti lac sov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIfauffiff, r MONTHLY PRODUCTION REPO Til�� 20 AAC 25.23o Name of Operator HILCORP ALASKA, LLC - Feb-23 1. Well No. 2 API No. 3. Type 4. Field & 5. Mettwd 6. Days in Oper. 7. Avg. FTP DAILY AVG. PRODUCTION TOTAL MONTHLY PRODUCTION W)=XXIOOFXX-XX (see Pool (see prig(see B. OIL 9. 10-(i>.S 1L OIL 12-WATER 13-GAS instruct.) Code instinct.) instruct.) (BBL) WATER(BBL) (BBL) (BBL) (BBL) (BBL} Wha evGukh 01 50-231-20R79-00-00 2 94❑500 $ ❑ ❑ 0 0 0 0 ❑ ❑ I hereby certify that the foregoing is true and correct to the best of my knowledge. Dale of TitleProducfion Ana" Revision? AUthDnmd Name and Digtal Signature with date_ Revision Jennifer °°�"��"°� r�r Conrad Phoney 713 2892889 Dove (5388onrJo,s3ea TOTAL OwbademaiL= Iennlfer.doyeftllcor0.COm 1 1 Furor 10-405 R. 1012021 20 AAC 25 235 Submit in PDF format to aog. reporting®alaska gov 1('.',0NF1BEdNT1ALJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1_ Facility Number 2_ Facility Name 3- Field 4. Operator 5_ MonthlYear of Disposition 231D00006 Whiskey Gulch Whiskey Gulch Hilcorp Alaskaa LLC January-23 Disposition Volume MCF 20_ For production Gam multiple pools, list contribution of each pool as a percent of Total Volume_ 6_ Sold Pool Name Pool Code Percent Z Reinjected Whiskey Gulch 940500 100.0D% 0_ Flared or vented 1 hour or less 9_ Flared orvented more than 1 hour (see instr) 10_ Pilot and Purge 11. Assist Gas 12_ Fuel gas used in lease operations_ 13. Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 5-131 Lease Use MCF 15_ NGL Gas Equivalent Conservati MCF 16 Purchased gas Waste MCF 17_ Transferred from Reviewed by: COMMISSIONER 10_ Transferred to (Express as a negative if) Comm_ comm 19. Remarks. I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? C Date of Revision: Title_ Production Analyst Authorized Name and Digital Signature veth date_ Jennifer Dovelennifer = piano` � on- Contact Phone_ 713 2892889 Note: All volumes must be corrected to pressure Dove 5388 oa.'� �,�,,,a,z,e�� of 14.65 psis and to a temperature of 60° F. Authority 20 AA C 25.235. Contact Email: lennifecdove(�hilcorp.com Form 10 22 Revaed 1012021 20PAC25235 submit in POF format to aogcc.raW"iing@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25230 C',ONF IllENFIAL Name of Operator 0 HILCORP ALASKA. LLC Month and Year. Jan-23 1. Well No. 2. API No. 3. Type 4. Field & 5. Method 5. Days in Oper. T. Avg. FTP DAILY AVG. PRODUCTION TOTAL MONTHLY PRODUCTION 5(T)= X)=xX-XX I. Pool (see 1 Psg(se. g. OIL 9. 10_GAS 1LOIL 12_WATER 13_GAS instruct) Code instruct.)instruct.) IBBL) WATER(BBL) (BBL( (BBL) (BBL) (BBL) 01 510,231-20079-00-00 1 2 940500 1 B 1 M 01 01 01 01 nl 1)1 0 0 I hereby cerkty that the foregai g is true and correct to the best of my knowledge. 14 TAIeProduction Analyst Date of Revisim7 Revision_ Authoreed Name and DgitalSgnaturewith date_ Contact Phone 713 21192889 Jennifer PE3�l),-ib,a�n� nn �`� Dove (5388) TOTAL oae z®_ozu ruiz�e mm ConlaclEmail:: iennifecdoveCdhilcoro.com Farm 10-005 Rev_ 10f2021 20 AAC 25 235 Submit in PDF fennat to aog. mperling*alaska gov 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: 01/20/2023 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WHISKEY GULCH 1 PTD: 221-046 API: 50-231-20079-00-00 ROUTINE CORE ANALYSIS REPORT(01/03/2023) **CONFIDENTIAL** 1. FINAL REPORT 2. MS EXCEL DATA FILES a. BATCH CLEANED (25-Feb-2022) b. FLOW_THRU CLEANED (11-Feb-2022) c. RCAL FINAL (16-Dec-2022) Please include current contact information if different from above. By Meredith Guhl at 3:22 pm, Jan 20, 2023 221-046 T37455 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.20 15:24:02 -09'00' S ('Of0NF 11)lj\T'1'lAL ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION L Faolity Number 2 Facility Name 3 Field 4. Operator 5_ ManihlYear of Disposdion 231000006 Whiske Gulch Whisk Gulch Riled AlaskaLLC December-22 Disposition Volume MCF 20. For production from multipfe poois, fist conbibuhbn of each pool as a percent of Total Voume. 6 Sold Pool Name Pool Code Percent Whiskey Gulch 940500 10000% 7_ Reinjected 0_ Flared or vented 1 hour or less 9_ Flared or vented more than 1 hour (see insir) 10. Pilot and Purge 11_ Assist Gas 12. Fuel gas used in lease operations. 13. Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) Lease Use MCF 15_ NGL Gas Equivalent Conservati MC F 16_ Purchased gas Waste WE 17. Transferred from: Reviewed by COMMISSIONER 18. Transferred to- (Express as a negative #) Comm Icorm, 19_ Remarks_ hereby certify that the foregoing is true and correct to the best of my knowledge_ Revision? Date of Revision' Title Production Analyst Authorized Name and Digital Signature vlih date_ Jennifer Dave Contact Phone: 7132892889 Note: All volumes must be corrected to pressure Jennifer of 14.65 Asia and to a temperature of 60' F. Contad Email: lennifecdove(arhilwrp.com Authority 20 AAC 25.235. Form 10-422 Peevised 10/2021 20 A1C 25.235 Submit In PDF formrt toacgw.reponing@alaska.gov STATE OF ALASKA OIL AND GAS CON; MONTHLY PRODI 20 AAC 25.230 �GrzON { Il1117AN 1IAL Name of Operatcr HILCORP ALASKA, LLC Month and Year: Dec-22 1. Well No. 2 API No. 3. Type 4. Field & 5. McOmd ®. Days in Oper. 7. Avg. FTP DAILY AVG. PRODUCTION TOTAL MONTHLY PRODUCTION 50-)O(X X7)33(-XX-7IX (see Peel (see psg (see g. OIL 9. iR GAS 1 L OIL 12 WATER 13 GAS instruct.) Cade instruct.) instruct.} (BBL) WATER(BBL) (BBL) (BBL) (BBL( (BBL) Whisk Gulch 01 50-231-20079-0"Ll 2 94050n B 0 0 0 0 0 0 0 0 1 hereby cerOfy that the feregoing a true and canectto the best of my knowledge. TNeProduction Analyst Date of Revision? 14_ AuUmnood Name and DgR l Signature with date_ Revision Jennifer jjq DN �nm o—tom, Contact Phoney 713.289 2889 Dove (5388) c — o,a tia usm TDTAL contact Emaa:: iennifer.dovePhilcorn.com Farm ICLAM Rev_ 1012021 20 AAC 25.235 Submit in PDF format to aogcc mpoding@.task. gav CONFIDENTIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1_ Faulty Number 2_ Facility Name 3_ Field 4. Operator 5_ MorAhlyear of Disposition 231000006 Whisk Gulch Whisk Gulch Hilw Alaska.LLC November-22 Disposition Volume MCF 20_ Forpmduc#on Imm multiple pods, list wnbitwtion of each pool as a percent of Total Volume_ 6. Sold Pool Name Pool Code Percent Whiskey Gulch 940500 1D0.00% 7. Reinjected 0_ Flared or vented 1 hour or less 9_ Flared or vented more tlmn 1 hour (see insfir 10_ Pilotand Purge 11_ Assist Gas 12_ Fuel gas used in lease operations. Official Use 13. Other (see instructions) Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) Lease Use MCF 15. NGL Gas Equivalent Conservati MCF 16. Purchased gas Waste MCF Reviewed by 17_ Transferred from COMMISSIONER Comm. lComm. 16_ Transferred to- (Express as a negative #) 19_ Remarks_ hereby certify that the foregoing is true and tarred to the best of my knowledge. Revision? C Date of Revision_ Title: Production Analyst Authorized Name and Digital Signature with date: Jennifer Dove Jennifer Contact Phoney 7132892889 Note, All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60' F. Dove (5388 os� � °"e1 �"p-'�'�4'� Authority 20 AAC 26.235. Contact Email: lennifer.doverdhilcorp.rom Pam 10422 Fev6ld 10f2021 20 PAC 25.235 Submit in PDF format to aoga.reporting@alaska 4pv ALASKA. LLC wxxx X7000(-1 x xx (see Pool nsWcl.) Code Jennifer on. �a�.a�m� IveeA Dove (5388), STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CC MONTHLY PRODUCTION RE 20 AAC 25.230 Date of Revision? d Revision: Contact Phone: 713 289 2889 Contact Em d:: 0ennifer.dovei f.lONFIDl.\ TIAL Form 10-405 Rev. 1012021 20 AAC25.235 Submit in PDF formal to acgcc.mporhng@alaska.gev STATE OF ALASKA (CO.ONFIDIZATIALi ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1_ Facility Number 2_ Facility Name 3- Field 4. Operator 5_ MonthlYear of Disposition 231000006 Whiskey Gulch Whiskey Gulch Hilcorp Alaskaa LLC October-22 Disposition Volume MCF 20_ For production Gam multiple pools, list contribution of each pool as a percent of Total Volume_ 6_ Sold Pool Name Pool Code Percent Z Reinjected Whiskey Gulch 940500 100.00% 0_ Flared or vented 1 hour or less 9_ Flared orvented more than 1 hour (see instr) 10_ Pilot and Purge 11. Assist Gas 12_ Fuel gas used in lease operations_ 13. Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-131 Lease Use MCF 15_ NGL Gas Equivalent Conservati MCF 16 Purchased gas Waste MCF 17_ Transferred from Reviewed by: COMMISSIONER 10_ Transferred to (Express as a negative if) Comm_ Comm_ 19. Remarks. I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? C Date of Revision: Title_ Production Analyst Authorized Name and Digital Signature with date_ `V�a'3aMa� Jennifer Dove Jennifer Contact Phone_ 7132892889 Note: All volumes must be corrected to pressure ( oa �agmre i�teef of 14.65 Asia and to a temperature of 60° F. Dove (5388) o,nea n.uau-0cm Authority 20 AA C 25.235. Contact Email: lennifecdove(�hilcorp.com Form 10422 Revaed 1012021 20 PAC 25235 submit in Par format to aogcc.raW"iing@alaska.gov 01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Y T r MONTHLY PRODUCTION REPORT � JFO �+ IDEAN I}} L 20 AAC 25230 LLC 0 Month and Year: 44�JA:1:67:C17:6:a:6:a:1 5P231-20019-00-00 (see Pod (see instruct( Code insl 2 940500 0 Jennifer , ON. .1mm w.4ln�ea). Dove (5388) psg (see nstruct.) Revisim? Date of Revfsian_ Contact Phoney 713 289 2889 Contact Email:: iennifer.clove. 14_ TOTAL Farm 10A05 Rev_ 10R021 20 AAC 25 235 Sdb.k in PDF format to aog. mparling*alaska gov CONFIDENTIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1_ Facility Number 2_ Facility Name 3- Field 4. Operator 5_ MonthlYear of Disposition 231D00006 Whiskey Gulch Whiskey Gulch Hilcorp Alaskaa LLC September-22 Disposition Volume MCF 20_ For production mom multiple pock, list contabution of each pool as a percent of Total Volume_ 6_ Sold Pool Name Pool Code Percent Z Reinjected Whiskey Gulch 940500 100.0D% 0_ Flared or vented 1 hour or less 9_ Flared orvented more than 1 hour (see instr) 10_ Pilot and Purge 11. Assist Gas 12_ Fuel gas used in lease operations_ 13. Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 5-131 Lease Use MCF 15_ NGL Gas Equivalent Conservati MCF 16 Purchased gas Waste MCF 17_ Transferred from Reviewed by: COMMISSIONER 10_ Transferred to (Express as a negative if) Comm_ Comm_ 19. Remarks. I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? C Date of Revision: Title_ Production Analyst Authorized Name and Digital Signature veth date_ Jennifer Dove Contact Phone_ 713 2892889 Note: All volumes must be corrected to pressure Jennifer i""Rtl" g°w` of 14,65 psia and to a temperature oF60° F. Doge 5388 �1 m4is a� ,a,,,�z® Contact Lmail: lennifer.dovefahilcorp.com Authority 20 AA 25.235. Form 10 22 Revaed 1012021 20PAC25235 submit in POF format to aogcc.raW"iing@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO eSSION MONTHLY PRODUCTION RE 1",O F ��1``TI 1 L za AAc zs_z3o ` L Name of Operator 0 HILCORP ALASKA. LLC aa,c 1. Well No. 2. API No. 3. Type 4. Field & 5. Method 5. Days in UP- 1. Avg. FTP DAILY AVG. PRODUCTION TOTAL MONTHLY PRODUCTION 50.X)IX-7Q70IX-XX-XX {see Pod (see psg [see g. OIL 9. 10_ GAS 11.01E 12_ WATER 13_ GAS nstrud) Code imil instruct) (BBL) I WATER(BBL) I (BBL( (BBL) (BBL) (BBL) Whiskey Gull 5P231-21]074-00-00 2 940500 B 1 01 01 01 01 nj 01 01 0 I hereby cartity that the foregai g is true and correct to the best of my knowledge. 14 TAIeProduction Analyst Date of Revisim7 Revision_ Authoreed Name and Digital Signature with date_ 1SamN�tr te.ieoore Jennifer (2=) Contact Phone 7132892889 Dove (5388) TOTAL Contact Email:: iennifer.clovePhilcorp.com Farm 10A05 Rev_ 10R021 20 AAC 25 235 Sub.i in PDF farm.[to aog.ruparlinci laska gov C.ONI{IDEAN 1'IAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1_ Facility Number 2_ Facility Name 3 Field 4. Operator 5_ MonthlYear of Disposition 231D00006 Whiskey Gulch Whiskey Gulch Hilcorp Alaskaa LLC Mar22 Disposition Volume MCF 20_ For production Gam multiple pools, list contribution of each pool as a percent of Total Volume_ 6_ Sold Pool Name Pool Code Percent Z Reinjected Whiskey Gulch 940500 100_DD% 0_ Flared or vented 1 hour or less 9_ Flared orvented more than 1 hour (see instr_) 10_ Pilot and Purge 11. Assist Gas 12_ Fuel gas used in lease operations_ 13. Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-131 Lease Use MCF 15_ NGL Gas Equivalent Conservati MCF 16 Purchased gas Waste MCF 17_ Transferred from Reviewed by: COMMISSIONER 10_ Transferred to (Express as a negative if) Comm_ Comm_ 19. Remarks. I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? C Date of Revision: Title_ Production Analyst Authorized Name and Digital Signature with date_ Jennifer Dove Contact Phone_ 713 2892889 Note: All volumes must be corrected to pressure � Jennifer w3��. ' of 14,65 Asia and to a temperature oF60°F. ^^ r1 Dove (5388) Contact Email: lennifecdove(�hilcorp.com Authority 20 AA 25.235. Form 10 22 Revaed 1012021 20 PAC 25.235 subm a in PO F format to aogcc.raWiliinglaalaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25230 FCONTFIl)EXI'IA J, Name of Operator 0 anu rear: MonthuF22 HILCORP ALASKA. LLC J 1. Well No. 2. API No. 3. Type 4. Field & 5. Method 5. Days in Oper. 1. Avg. FTP DAILY AVG. PRODUCTION TOTAL MONTHLY PRODUCTION 5(T)= X)=xX-XX I. Pool (see 1 Psg(see g. OIL 9. 10_13AS 11 OIL 12_WATER 13_GAS iinstruct.) Code insWd.) instruct.) IBBL) I WATER(BBL) I (BBL) I (BBL) (BBL) 1 Whiskey Gulrh 0l 1 5P231-200791IU-00 1 2 940500 1 B 1 01 01 01 01 nj I)l 01 0 I hereby cartity that the foregoing is true and correct to the best of my knowledge. 14 TteProduction Analyst Date of Revisim7 Revision_ Authoreed Name and Digital Signature with date_ Jennifer Pia;"� Dove {538$) ca: �,.inmmt.e�tvrey as o�: m�nv.ry ram�ausm Contact Phoney 713 2892889 TOTAL Contact Email:: ienn&er.dove@hilcorp.com Farm 10A05 Rev_ 10f2021 20 AAC 25 235 Submit in PDF format to aogcc repartinci laska gm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d/> )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 1:21 pm, Sep 01, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH :HOOVLWH LQVSHFWLRQ UHTXLUHG SHU $$& 3URYLGH GD\V QRWLFH IRU $2*&& LQVSHFWRU WR DFFRPSDQ\ LQVSHFWLRQ YLVLW %-0 ; '/% 6XVSHQVLRQ H[SLUHV '65*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.10.03 09:53:17 -08'00' RBDMS JSB 100522 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ sZϮ tĞůůEĂŵĞ͗tŚŝƐŬĞǇ'ƵůĐŚϬϭ W/EƵŵďĞƌ͗ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗ >ĞŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϰϬϯ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗:ƵĂŶŝƚĂ>ŽǀĞƚƚ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϮϭͲϬϰϲ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗<ĂƚŚĞƌŝŶĞK͛ŽŶŶŽƌ KĨĨŝĐĞ͗ϵϬϳͲϳϳϳͲϴϯϳϲ Ğůů͗ϮϭϰͲϲϴϰͲϳϰϬϬ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶZƵƉĞƌƚ Ğůů͗ϵϬϳͲϯϬϭͲϭϳϯϲ DĂǆǆƉĞĐƚĞĚ,W͗ϴϱϱƉƐŝΛϭϵϳϲ͛ds Ϭ͘ϰϯϯƉƐŝͬĨƚŐƌĂĚŝĞŶƚƚŽƐƵƌĨĂĐĞ DW^W͗ϳϰϬƉƐŝ >ŽŶŐƚĞƌŵ^/dW tĞůů,ŝƐƚŽƌǇ͗ tŚŝƐŬĞǇ'ƵůĐŚͲϬϭŝƐĂŶĞǆƉůŽƌĂƚŝŽŶǁĞůůĚƌŝůůĞĚŶĞĂƌEŝŶŝůĐŚŝŬ ŝŶƚŽƚŚĞdǇŽŶĞŬŐĂƐƐĂŶĚƐ͘/ƚǁĂƐĚƌŝůůĞĚŝŶƵŐƵƐƚŽĨϮϬϮϭ͘ dŚĞůŽǁĞƌƉĂƌƚŽĨƚŚĞǁĞůůďŽƌĞǁĂƐĂďĂŶĚŽŶĞĚǁŚĞŶĚƌŝůůŝŶŐĚĞĞƉĞƌĚŝĚŶŽƚĨŝŶĚĂŶǇŽŝůƐĂŶĚƐ͘/ƚǁĂƐĂďĂŶĚŽŶĞĚĂŶĚůŝŶĞƌ ĐĞŵĞŶƚĞĚŝŶƉůĂĐĞ͘,ŝůĐŽƌƉŝŶĚŝǀŝĚƵĂůůǇƚĞƐƚĞĚŵƵůƚŝƉůĞƐĂŶĚƐŝŶƚŚĞǁĞůů͕ƚŚĞƌĞǁĞƌĞƐŽŵĞŐĂƐƐŚŽǁƐďƵƚƚŚĞǁĞůůĚŝĞĚŽĨĨ ƌĂƉŝĚůǇ͘tŚŝůĞƚŚĞƌĞĂƌĞŶŽŝŵŵĞĚŝĂƚĞƉůĂŶƐĨŽƌƚŚĞǁĞůůďŽƌĞ͕,ŝůĐŽƌƉŝŶƚĞŶĚƐƚŽĞǀĂůƵĂƚĞĂŶĚƚĞƐƚƐŽŵĞƐŚĂůůŽǁĞƌƐĂŶĚƐ ďĞůŽǁƚŚĞĐĂƐŝŶŐƐŚŽĞŝŶϮϬϮϯ͘ >ĞĂƐĞŝŶĨŽƌŵĂƚŝŽŶ͗ >ϯϵϮϲϲϲ͗ ͻϮ͕ϯϰϴ͘ϱϮŐƌŽƐƐĂĐƌĞƐ͖ ͻϭϬϬй^ƚĂƚĞŵŝŶĞƌĂůŝŶƚĞƌĞƐƚ͖ ͻϭϬϬй,ŝůĐŽƌƉtŽƌŬŝŶŐ/ŶƚĞƌĞƐƚ͖ ͻĨĨĞĐƚŝǀĞĂƚĞ͗ϯͬϭͬϮϬϭϱ͖ ͻǆƉŝƌĂƚŝŽŶĂƚĞ͗ϮͬϮϴͬϮϬϮϱ͖ tĞůůďŽƌĞŽŶĚŝƚŝŽŶ x ϳͲϱͬϴ͟ĐĂƐŝŶŐƚĞƐƚĞĚƚŽϯϱϬϬƉƐŝƵŶĚĞƌWdϮϮϭͲϬϰϲŽŶϴͬϮϲͬϮϭ x EŽĂďŶŽƌŵĂůůǇŐĞŽƉƌĞƐƐƵƌĞĚƐƚƌĂƚĂ x /;ϳͲϱͬϴ͟ǆϭϬͲϯͬϰ͟ĂŶŶƵůƵƐͿǁŝůůŶŽƚƉĂƐƐĂƉƌĞƐƐƵƌĞƚĞƐƚ WƌŽĐĞĚƵƌĞ͗ ϭ͘ ZhůŝŶĞWdůƵďƌŝĐĂƚŽƌƚŽϮϱϬ>ͬϮϬϬϬ,/ Ϯ͘ ^ĞƚWĂďŽǀĞƚŚĞŽƉĞŶƉĞƌĨŽƌĂƚŝŽŶƐĂƚцϮϬϯϱ͛D;ƉůƵŐŵƵƐƚď ĞǁŝƚŚŝŶϱϬ͛ŽĨƉĞƌĨŽƌĂƚŝŽŶƐͿ ϯ͘ ƵŵƉďĂŝůϯϬ͛ŽĨĐĞŵĞŶƚŽŶƚŽƉŽĨƚŚĞƉůƵŐ͕ĞǆƉĞĐƚĞĚdKϮϬϬϱ͛D͘ ϰ͘ ZůŝŶĞ ϱ͘ ZhƉƵŵƉΘĨŝůůǁĞůůǁŝƚŚĨƌĞƐŚǁĂƚĞƌ;ϵϯďďůĨŝůůƵƉǀŽůƵŵĞͿ ϲ͘ dŽƉǁĞůůǁŝƚŚϭďďůĚŝĞƐĞůĨŽƌĨƌĞĞǌĞƉƌŽƚĞĐƚ ϳ͘ WdƉůƵŐĂŶĚĐĂƐŝŶŐƚŽϮϬϬϬƉƐŝ͕ĐŚĂƌƚƉƌĞƐƐƵƌĞƚĞƐƚ ƚƚĂĐŚŵĞŶƚƐ ϭ͘ ƵƌƌĞŶƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ǁĞůůŚĞĂĚƐĐŚĞŵĂƚŝĐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:>>ϬϰͬϭϴͬϮϮ ^,Dd/tĞůů͗tŚŝƐŬĞǇ'ƵůĐŚϭ Wd͗ϮϮϭͲϬϰϲ W/͗ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ WZ&KZd/KEd/> ŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ dϭϬ Ϯ͕Ϭϲϰ͛ Ϯ͕Ϭϳϴ͛ ϭ͕ϵϳϲ͛ ϭ͕ϵϵϬ͛ ϭϰ͛ϬϮͬϭϳͬϮϮ KƉĞŶ dϭϰ Ϯ͕ϴϵϬ͛ Ϯ͕ϵϭϬ͛ Ϯ͕ϲϱϯ͛ Ϯ͕ϲϲϵ͛ ϮϬ͛ϬϮͬϭϲͬϮϮ /ƐŽůĂƚĞĚ dϭϴ ϯ͕ϯϳϯ͛ ϯ͕ϯϴϭ͛ ϯ͕Ϭϰϱ͛ ϯ͕Ϭϱϯ͛ ϴ͛ϬϭͬϭϭͬϮϮ /ƐŽůĂƚĞĚ dϰϴ ϰ͕ϰϵϴ͛ ϰ͕ϱϭϴ͛ ϯ͕ϵϲϱ͛ ϯ͕ϵϴϭ͛ ϮϬ͛ϭϮͬϮϴͬϮϭ /ƐŽůĂƚĞĚ dϰϴ ϰ͕ϱϰϰ ϰ͕ϱϲϰ ϰ͕ϬϬϯ ϰ͕Ϭϭϵ ϮϬ͛ϭϮͬϮϵͬϮϭ /ƐŽůĂƚĞĚ dϲϱ ϲ͕ϭϯϳ͛ ϲ͕ϭϲϭ͛ ϱ͕ϯϭϯ͛ ϱ͕ϯϯϯ͛ Ϯϰ͛ϭϮͬϮϳͬϮϭ /ƐŽůĂƚĞĚ dϲϱ ϲ͕ϭϰϯ͛ ϲ͕ϭϱϱ͛ ϱ͕ϯϭϵ͛ ϱ͕ϯϯϭ͛ ϭϮ͛ϭϮͬϮϮͬϮϭ /ƐŽůĂƚĞĚ KWE,K>ͬDEdd/> ϭϬͲϯͬϰ͟ Ɛƚ͘dKΛ^ƵƌĨĂĐĞ;ϭϬϬйĞǆĐĞƐƐͿZĞƚƵƌŶƐƚŽƐƵƌĨĂĐĞ;ϴͬϭϮͬϮϭͿ ϳͲϱͬϴΗ ϵͲϳͬϴ͟ŚŽůĞ͗ϯϯϯďďůƐϭϮ͘ϬƉƉŐdǇƉĞ/Ͳ//ůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďǇϯϬďďůƐϭϱ͘ϴƉƉŐdǇƉĞ/Ͳ//ƚĂŝů ĐĞŵĞŶƚ͘EŽůŽƐƐĞƐ͘ϭϬďďůƐƐƉĂĐĞƌďĂĐŬƚŽƐƵƌĨĂĐĞ;ϰϬďďůƐƐƉĂĐĞƌƉƵŵƉĞĚͿ͘sŽůƵŵĞƚƌŝĐdŽ ďĂƐĞĚŽŶƐƉĂĐĞƌƌĞƚƵƌŶƐсΕϳϱϬ͛D͘>ŽŶϴͬϮϵͬϮϭƐŚŽǁƐdŽdKΛΕϭϰϯϬ͛͘ ϰͲϭͬϮ͟ dKΛϳ͕ϰϬϰ;dĂŐŐĞĚͿ dсϭϬ͕Ϯϳϭ͛ ;DͿ ͬ dсϵ͕ϯϯϮ͛;dsͿ ϭϲ͟ KƌŝŐ͘<ůĞǀ͗͘ϭϴ͛ͬ'>ůĞǀ͗͘ϮϬϮ͘ϲ͛ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ dKΛцϭϱϬϭ͛ Wdс ϳ͕ϰϬϰ͛;DͿͬWdс ϲ͕ϱϬϴ͛;dsͿ ϰͲϭͬϮ͟ dϲϱ ϲͲϯͬϰ͟,ŽůĞ ϵͲϳͬϴ͟,ŽůĞ ϭϯͲϭͬϮ͟,ŽůĞ dK ƚĂŐŐĞĚΛ ϳϰϬϰ͛D dϰϴ dϭϴ dϭϰ dϭϬ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌʹƌŝǀĞŶ ƚŽ^ĞƚĞƉƚŚ ϴϰ yͲϱϲ tĞůĚ ϭϱ͘Ϭϭ͟ ^ƵƌĨ ϭϮϬ͛ ϭϬͲϯͬϰ͟ ^ƵƌĨƐŐ ϰϱ͘ϱ >ͲϴϬ tͬ ϵ͘ϵϱϬ͟ ^ƵƌĨ ϭ͕ϱϬϭ͛ ϳͲϱͬϴΗ /Ŷƚ͘ƐŐ Ϯϵ͘ϳ >ͲϴϬ ϲ͘ϴϳϱ͟ ^ƵƌĨ ϳ͕ϳϬϮ͛ ϰͲϭͬϮΗ ďĂŶĚŽŶŵĞŶƚ>Ŷƌ ϭϮ͘ϲ >ͲϴϬ /d ϯ͘ϵϱϴ͟ ϳ͕ϱϯϴ͛ ϭϬ͕Ϯϲϴ͛ :t>Zzd/> EŽ͘ĞƉƚŚ D ĞƉƚŚ ds/ K /ƚĞŵ ϭ ϭ͕ϮϮϬ͛ ϭ͕Ϯϭϱ͛ ϲ͘ϴϳϱ͟ ϵ͘ϵϱϬ͟ ϳͲϱͬϴ͟^ǁĞůůWĂĐŬĞƌ Ϯ Ϯ͕ϳϵϬ͛ Ϯ͕ϱϳϭ͛ /W ϯ ϯ͕ϭϴϬ͛ Ϯ͕ϴϴϴ͛ /W ϰ ϯ͕ϲϯϬ͛ ϯ͕Ϯϱϰ͛ ϳͲϱͬϴ͟ŽŵƉŽƐŝƚĞƌŝĚŐĞWůƵŐ;ŵĂŐŶƵŵͿ ϱ ϰ͕ϳϵϬ͛ ϰ͕ϮϬϱ͛ ϳͲϱͬϴ͟ŽŵƉŽƐŝƚĞƌŝĚŐĞWůƵŐ;ŵĂŐŶƵŵͿ ϲ ϳ͕ϱϯϴ͛ ϲ͕ϲϰϬ͛ ϭ͘ϴϳϱ͟ ϰ͘ϱϬϬ͟ ,ĂůůŝďƵƌƚŽŶ,<ŝƐĐŽŶŶĞĐƚdŽŽů BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗:>>ϴͬϯϭͬϮϮ WZKWK^tĞůů͗tŚŝƐŬĞǇ'ƵůĐŚϭ Wd͗ϮϮϭͲϬϰϲ W/͗ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ WZ&KZd/KEd/> ŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ dϭϬ Ϯ͕Ϭϲϰ͛ Ϯ͕Ϭϳϴ͛ ϭ͕ϵϳϲ͛ ϭ͕ϵϵϬ͛ ϭϰ͛&ƵƚƵƌĞ /ƐŽůĂƚĞĚ dϭϰ Ϯ͕ϴϵϬ͛ Ϯ͕ϵϭϬ͛ Ϯ͕ϲϱϯ͛ Ϯ͕ϲϲϵ͛ ϮϬ͛ϬϮͬϭϲͬϮϮ /ƐŽůĂƚĞĚ dϭϴ ϯ͕ϯϳϯ͛ ϯ͕ϯϴϭ͛ ϯ͕Ϭϰϱ͛ ϯ͕Ϭϱϯ͛ ϴ͛ϬϭͬϭϭͬϮϮ /ƐŽůĂƚĞĚ dϰϴ ϰ͕ϰϵϴ͛ ϰ͕ϱϭϴ͛ ϯ͕ϵϲϱ͛ ϯ͕ϵϴϭ͛ ϮϬ͛ϭϮͬϮϴͬϮϭ /ƐŽůĂƚĞĚ dϰϴ ϰ͕ϱϰϰ ϰ͕ϱϲϰ ϰ͕ϬϬϯ ϰ͕Ϭϭϵ ϮϬ͛ϭϮͬϮϵͬϮϭ /ƐŽůĂƚĞĚ dϲϱ ϲ͕ϭϯϳ͛ ϲ͕ϭϲϭ͛ ϱ͕ϯϭϯ͛ ϱ͕ϯϯϯ͛ Ϯϰ͛ϭϮͬϮϳͬϮϭ /ƐŽůĂƚĞĚ dϲϱ ϲ͕ϭϰϯ͛ ϲ͕ϭϱϱ͛ ϱ͕ϯϭϵ͛ ϱ͕ϯϯϭ͛ ϭϮ͛ϭϮͬϮϮͬϮϭ /ƐŽůĂƚĞĚ KWE,K>ͬDEdd/> ϭϬͲϯͬϰ͟ Ɛƚ͘dKΛ^ƵƌĨĂĐĞ;ϭϬϬйĞǆĐĞƐƐͿZĞƚƵƌŶƐƚŽƐƵƌĨĂĐĞ;ϴͬϭϮͬϮϭͿ ϳͲϱͬϴΗ ϵͲϳͬϴ͟ŚŽůĞ͗ϯϯϯďďůƐϭϮ͘ϬƉƉŐdǇƉĞ/Ͳ//ůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďǇϯϬďďůƐϭϱ͘ϴƉƉŐdǇƉĞ/Ͳ//ƚĂŝů ĐĞŵĞŶƚ͘EŽůŽƐƐĞƐ͘ϭϬďďůƐƐƉĂĐĞƌďĂĐŬƚŽƐƵƌĨĂĐĞ;ϰϬďďůƐƐƉĂĐĞƌƉƵŵƉĞĚͿ͘sŽůƵŵĞƚƌŝĐdŽ ďĂƐĞĚŽŶƐƉĂĐĞƌƌĞƚƵƌŶƐсΕϳϱϬ͛D͘>ŽŶϴͬϮϵͬϮϭƐŚŽǁƐdŽdKΛΕϭϰϯϬ͛͘ ϰͲϭͬϮ͟ dKΛϳ͕ϰϬϰ;dĂŐŐĞĚͿ dсϭϬ͕Ϯϳϭ͛ ;DͿ ͬ dсϵ͕ϯϯϮ͛;dsͿ ϭϲ͟ KƌŝŐ͘<ůĞǀ͗͘ϭϴ͛ͬ'>ůĞǀ͗͘ϮϬϮ͘ϲ͛ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ dKΛцϭϰϯϬ͛ D Wdс ϳ͕ϰϬϰ͛;DͿͬWdс ϲ͕ϱϬϴ͛;dsͿ ϰͲϭͬϮ͟ dϲϱ ϲͲϯͬϰ͟,ŽůĞ ϵͲϳͬϴ͟,ŽůĞ ϭϯͲϭͬϮ͟,ŽůĞ dK ƚĂŐŐĞĚΛ ϳϰϬϰ͛D dϰϴ dϭϴ dϭϰ dϭϬ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌʹƌŝǀĞŶ ƚŽ^ĞƚĞƉƚŚ ϴϰ yͲϱϲ tĞůĚ ϭϱ͘Ϭϭ͟ ^ƵƌĨ ϭϮϬ͛ ϭϬͲϯͬϰ͟ ^ƵƌĨƐŐ ϰϱ͘ϱ >ͲϴϬ tͬ ϵ͘ϵϱϬ͟ ^ƵƌĨ ϭ͕ϱϬϭ͛ ϳͲϱͬϴΗ /Ŷƚ͘ƐŐ Ϯϵ͘ϳ >ͲϴϬ ϲ͘ϴϳϱ͟ ^ƵƌĨ ϳ͕ϳϬϮ͛ ϰͲϭͬϮΗ ďĂŶĚŽŶŵĞŶƚ>Ŷƌ ϭϮ͘ϲ >ͲϴϬ /d ϯ͘ϵϱϴ͟ ϳ͕ϱϯϴ͛ ϭϬ͕Ϯϲϴ͛ :t>Zzd/> EŽ͘ĞƉƚŚ D ĞƉƚŚ ds/ K /ƚĞŵ ϭ ϭ͕ϮϮϬ͛ ϭ͕Ϯϭϱ͛ ϲ͘ϴϳϱ͟ ϵ͘ϵϱϬ͟ ϳͲϱͬϴ͟^ǁĞůůWĂĐŬĞƌ Ϯ цϮ͕Ϭϯϱ͛ цϭ͕ϵϱϮ͛ /WǁͬϯϬ͛ĞŵĞŶƚ;ĞƐƚ͘dKцϮ͕ϬϬϱ͛Ϳ ϯ Ϯ͕ϳϵϬ͛ Ϯ͕ϱϳϭ͛ /W ϰ ϯ͕ϭϴϬ͛ Ϯ͕ϴϴϴ͛ /W ϱ ϯ͕ϲϯϬ͛ ϯ͕Ϯϱϰ͛ ϳͲϱͬϴ͟ŽŵƉŽƐŝƚĞƌŝĚŐĞWůƵŐ;ŵĂŐŶƵŵͿ ϲ ϰ͕ϳϵϬ͛ ϰ͕ϮϬϱ͛ ϳͲϱͬϴ͟ŽŵƉŽƐŝƚĞƌŝĚŐĞWůƵŐ;ŵĂŐŶƵŵͿ :KLVNH\*XOFK 3URSRVHG:HOOKHDG ^ƚĂƌƚŝŶŐŚĞĂĚ͕ĂĐƚƵƐͲϮϵ>͕ ϭϲϯͬϰϯDǆϭϲΖ͛ ^Kt͕ ǁͬϮͲϮϭͬϭϲϱD^^K DƵůƚŝͲďŽǁů͕ĂĐƚƵƐD^ͲϮͲ W^͕ϭϲϯͬϰϯDǆϭϭϱD͕ǁͬϰͲ ϮϭͬϭϲϱD^^K ϭϲΖ͛ ϳϱͬϴΖ͛ ϭϬв͛͛ tŚŝƐŬĞǇ'ƵůĐŚηϭ ϭϲǆϭϬвǆϳϱͬϴ ϳϭͬϭϱϱDǆϰϭͬϭϲϱDƚƌĞĞ ĂƐƐǇĨŽƌǁĞůůƚĞƐƚŝŶŐ dƵďŝŶŐŚĞĂĚ͕ĂĐƚƵƐͲ,W^͕ ϭϭϱDǆϳϭͬϭϲϱD͕ǁͬϮͲ ϮϭͬϭϲϱD^^K CONFIDENTIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1_ Facility Number 2. Facility Name 3 Field 4. Operator 5_ MonthlYear of DLspasition 231000006 lWhiskey Gulch 1whiskey Gulch HiloxpAlasll Jul -22 Disposition Volume MCF 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume. 6_ Sold Pool Name Pool Code Percent 7_ Reinjected Whiskey Gulch 940500 10000% 8_ Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see instr.) 11)_ Pilotand Purge 11_ Assist Gas 12_ Fuel gas used in lease operations_ 13. Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) Lease Use MCF 15. NGL Gas Equivalent Canservati MCF 16_ Purchased gas Waste MCF 17_ Transferred from: Reviewed by COMMISSIONER 18_ Transferred to: (Express as a negative #) Comm. Comm. 19_ Remarks_ I hereby certify that the foregoing is true and correct to the best of my knov4edge. Revision? — Crate of Revision: Title: Production Analyst Authorized Name and Digital Signature with date_ Jennifer Do "�� °ox 9bnnifer Contact Phone_ 713 289 21 Note: All volumes must be corrected to pressure = �'��" of 14.65 psia and to a temperature of 60' F. Dove (5388) ati��rsi. Authority 20 AAC 25.235. +a�+++�� Contact Email eninder-daveahiloorio.com Form 10422 Revised 04/2020 20 AAC 25235 Submit in P D F format to aogcc.reportinika.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25230 CCONI� Il)1:1 TIAL Name of Operator 0 Month and Year: IT ALASKA. LLC JuF22 1. Well No. 2. API No. 3. Type 4. Field & 1 5. Method 5. Days m Oper. 7. Avg. FTP DAILY AVG. PRODUCTION TOTAL MONTHLY PRODUCTION 5(T)=)0D=XX-XX I. Pool I Psg [see g. OIL 9. 10_GAS 1LOIL 12_WATER 13_GAS instrud) Code insWd.) instinct.) (BBL) WATER(BBL) (BBL) (BBL) (BBL) (BBL) Whiskey Gulch 01 5101231-20(J79-00-00 1 2 940500 1 B 1 D 0 0 0 0 I)0 0 I hereby certity that the foregai g is true and correct to the best of my knowledge. 14 TAIeProduction Analyst Revisim7 Date of Revision_ Authro ed Name and Digital Signature with date_ Jennifer o)=.o�rs3eey. Dove (5388) _u oeeema<aia reuao-0sw Contact Phone' 7,32ss2138s TOTAL Contact Email:: iennifer.clovePhilcorp.com Farm 10A05 Rev_ 10f2Id21 20 AAC 25 235 Submit in PDF format to aogm reparting*alaska gm (CONFIDEANTIALi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1_ Facility Number 2_ Facility Name 3- Field 4. Operator 5_ MonthlYear of Disposition 231D00006 Whiskey Gulch Whiskey Gulch Hilcmp Alaskaa LLC June-22 Disposition Volume MCF 20_ For production Gam multiple pools, list contribution of each pool as a percent of Total Volume_ 6_ Sold Pool Name Pool Code Percent Z Reinjected Whiskey Gulch 940500 100_DD% 0_ Flared or vented 1 hour or less 9_ Flared orvented more than 1 hour (see instr_) 10_ Pilot and Purge 11. Assist Gas 12_ Fuel gas used in lease operations_ 13. Other (see instructions) Official Use Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-131 Lease Use MCF 15_ NGL Gas Equivalent Conservati MCF 16 Purchased gas Waste MCF 17_ Transferred from Reviewed by: COMMISSIONER 10_ Transferred to (Express as a negative if) Comm_ comm 19. Remarks. I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? C Date of Revision: Title_ Production Analyst Authorized Name and Digital Signature with date_ Jendemp er N Ui vg1etl w �no1er!)— Contact Phone_ 713 2892889 Note: All volumes must be corrected to pressure nr,. m aE. ��aa1 of 14.65 Asia and to a temperature of 60' F. Dove (5388) zoom n,a5 oannv -fieLdove Authority 20 AA 25.235. Contact Email: enn cDhilcor .core Form 10 22 Revaed 1012021 20 PAC 25.235 subm a in PO F format to aogcc.raWiliinglaalaska.gov 01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI5sl0 " i MONTHLY PRODUCTION REPORT �i��`r�� 1`Tr�,i1 20 AAC 25230 Month and Year: LLC I -I 44�JA:1:67:C17:6:a:6:a:1 5P231-20079-00-00 Ilea Pod I (see instruct) Code msWd.) 2 940500 0 WM1322 Jennifer Dove (5388) .,m,. _. psg (se. nshuct) Revisim? Date of Revfsian_ Contact Phoney 713 289 2889 Contact Email:: iennifecdove 14_ TOTAL Form 10-005 R. 1012021 20 AAC 25 235 Sdb.k in PDF format to aog. mp.rling*alaska gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION CONFIDENTIAL - i FACILITY REPORT OF PRODUCED GAS DISPOSITION 1_ Facility Number 2 FacilityName 3. Held lWhiskey 4. Operator 5_ Month/Year of Disposition 231 OD0006 Whisk Gulch Gulch Hilcor Alaska.LLC MAY 2022 Disposition Volume MCF 20. Forpmduction from multiple peots, list cunt ibudlon of each pool as a percent of Total Volume. 6 Sold Pool Name Pool Code Percent Whiskey Gulch 940500 100.00% 7. Reinjected 8_ Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see instr.) 10_ Pilot and Purge 11_ Assist Gas 12. Fuel gas used in lease operations. Official Use 13. Other (see instrudions) Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) Lease Use MCF 15. NGL Gas Lquivalent Conservati MCF 16. Purchased gas Waste MCF Reviewed by: 17_ Transterred from COMMISSIONER conno 1comm_ 18. Transferred to: (Express; as a negative #) 19_ Remarks- I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? ❑ Dale of Revision: TiOe_ Production Analyst Authorized Name and Digital Signature with date_ Contact Phone 7132892658 Note: All volumes must be corrected to pressure o,�„y s,,,e, ,,�.,a, Cyndi "ox mxW) of 14.65 psis and to a temperature of 60' F. HW n ewel Huynh (838)�=4W s143°3i Authority 20 AAC 25,235. CantactEmail: Chu nh hilcor .com Farm 10-422 Revised 0412020 20 AAC 25 235 Submit in PDF mmmat to aogcc repordng®alaska gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25 230 ECONFIDENTIAL Name of Operator FieldaMPuolWhiskey Gulch, Whiskey Gulch, Undefined Month and Year HILCORP ALASKA, LLC MAY 2022 1_ Well N. 2. API No. 3_ Type 4. BA & 5_ Method 6. Days in Oper 7_ Avg FTP DAILYAVG_ PRODUCTION TOTAL MONTHLY PRODUCTION 50-)=-)DXXX)D(XX (see Pool (see psg(see 8. OIL g. 10_GAS 11. OIL 12_WATER 13_GAS insrud) Cade instinct.) mshud.) (BBL) WATER(BBL) I (MCF) (BBL) (BBL( (MCF) 2 8 1 0 I henry certify that the foregoing is true and correct to the hest of my knowledge. 14. Tale: Production Analyst Dale of Revision? Revision: AuthDrized Name and Digital Signature with date: Cyndi ebb sou bycym'i al M emvia H„m Contact Phone' 7132892658 Huynh (838) TOTAL Contact Email: eh Wnh(a7hilCOfp_com ■ Form 10405 Rev. 1DI2021 20 AAC 25.235 Sul in PUF format to acgcc.reporting@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1C,ONFIDENTIALi FACILITY REPORT OF PRODUCED GAS DISPOSITION 1_ Facility Number 2 FacilityName 3. Held lWhiskey 4. Operator 5_ Month/Year of Disposition 231 OD0006 Whisk Gulch Gulch Hilcor Alaska.LLC April 20 Disposition Volume MCF 20. Forpmduction from multiple pacts, list cent ibudlon of each pool as a percent of Total Volume. 6 Sold Pool Name Pool Code Percent Whiskey Gulch 940500 100.00% 7. Reinjected 8_ Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see instr.) 10_ Pilot and Purge 11_ Assist Gas 12. Fuel gas used in lease operations. Official Use 13. Other (see instructions) Authorization Safety MCF 14. TOTAL VOLUME (ITEMS 6-13) Lease Use MCF 15. NGL Gas Lquivalent Conservati MCF 16. Purchased gas Waste MCF Reviewed by: 17_ Transterred from COMMISSIONER conno 1comm_ 18. Transferred to: (Express; as a negative #) 19_ Remarks- I hereby certify that the foregoing is true and correct to the best of my knowledge. Revision? ❑ Dale of Revision: TiOe_ Production Analyst Authorized Name and Digital Signature with date_ C Contact Phone = 713 289 2658 Note: All volumes must be corrected to pressure ndlnN� y '3' of 14.65 psis and to a temperature of 60' F. ox _ roy.�n r®el Huynh (838) MA° 142° 0- Authority 20 AAC 25,235. Contact Lmail: chrinh hilcor .com Farm 10-422 Revised 0412020 20 AAC 25 235 Submit in PDF mmmat tD aogcc repordng®alaska gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25 230 =()N,(",ONFIDENTIAd TF4 11, Name of Operator Fieldald PoolWhiskey Gulch, Whiskey Gulch, Undefined Month and Year HILCORP ALASKA, LLC Apn12022 L We11 No_ 2. API No. 3_ Type 4. BA & 5_ Method 6. Days in Oper 7_ Avg FTP DAILYAVG_ PRODUCTION TOTAL MONTHLY PRODUCTION 50-)WFX%X)OWO(XX (see Pool (see psg (see 8. OIL 11 10_ GAS 11. OIL 12_ WATER 13_ GAS insuid) Code instruct.( instruct.) (BBL) WATER(BBL) (MCF) (BBL) (BBL( (MCF) Whiskey Gllch0l 50.231-20o7g-00-00 1 2 g40500 8 1 0 0 0 0 0 0 0 0 I henry certify that the foregoing is true and correct to the hest of my knowledge. 14. TNe: Production Analyst Dale of Revision? Revision: AuthDr¢ed Name and Digital Signature with date: D�ah 9a�gnlmi Cyl Hu h(33s) Contact Phone 7132892658 oar DIN H1C,. H9 htl 1- HUph (838) WW rorAL Contact Email: ChuVnh(a7hilCOfp_com Fonm 1041)5 Rev. 10I2021 20 AAC 25.235 SubmR in PUF format to acgcc.mporting@alaska.gov 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 202.6' BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 16" X-56 120' 10-3/4" L-80 1,480' 7-5/8" L-80 6,803' 4-1/2" L-80 9,329' 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 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, 580 sx6-3/4" TUBING RECORD N/A SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): L - 800 sx / T - 145 sx 7,538' Conductor Surface 1,501' L - 300 sx / T - 360 sx Driven STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 12/22/2021 1553' FSL, 1515' FEL, Sec 23, T4S, R15W, SM, AK 998' FNL, 963' FWL, Sec 25, T4S, R15W, SM, AK 221-046 / 321-594 Whiskey Gulch Prospect 220.6' 2,790' MD / 2,571' TVD HOLE SIZE AMOUNT PULLED 50-231-20079-00-00 Whiskey Gulch 1 168391 2128221 1300' FSL, 1259' FEL, Sec 23, T4S, R15W, SM, AK CEMENTING RECORD 2127908 SETTING DEPTH TVD 2125550 BOTTOM TOP 9-7/8" 94 bbls Surface 13-1/2"Surface CASING WT. PER FT.GRADE 12.6# 168660 170820 TOP SETTING DEPTH MD Surface Per 20 AAC 25.283 (i)(2) attach electronic information 29.7# 10,268' Surface 6,638' DEPTH SET (MD) PACKER SET (MD/TVD) 84# 45.5# 120' Surface 7,702' Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST 12/22/2021 Date of Test: 55 2/19/2022 24 Flow Tubing 0 4877 Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A4877 Flowing *** Please see attached schematic for perforation detail *** 0 Mudlogs, LWD Logs, OH Wireline logs (Borehole Volume, SW Core, Sonic, Micro imager), CBL 8/29/21, Perf Logs, XRMI Sr Res EngSr Pet GeoSr Pet Eng N/A N/A Oil-Bbl: Water-Bbl: 00513 August 28, 2021 August 9, 2021 ADL 392666 N/A N/A N/AN/A N/A 10,271' MD / 9,332' TVD WINJ SPLUGOther Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Meredith Guhl at 8:33 am, Apr 28, 2022 G Completed 12/22/2021 MDG RBDMS 4/28/2022 MDG SFD 8/9/2022 DSR-4/28/22BJM 11/29/22 / 321-436 -bjm 321-438 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval T 10 2,064' 1,976' 437' 437' 685' 685' 818' 817' 1196' 1191' 1399' 1385' 1718' 1679' 2048' 1963' 2853' 2622' 4449' 3924' 5064' 4426' 5290' 4610' 6095' 5277' 9910' 8976' Hemlock 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS ** Please see attached testing document for details ** BEL 40 BEL 5 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager T 6 T 10 Full lab analysis is still in processing. Will provide full report upon receiving. Attached core summary of 19 cores with depths/sample quality/formation. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME T 14A Permafrost - Top BEL 138 BEL 30 T 48 Formation at total depth: BEL 125 Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Report, Csg and Cmt Report, Formation tests summary, core summary. Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). T 65 T 70 T 100 Hemlock Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 4.27.2022 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.04.27 13:32:40 -08'00' Monty M Myers _____________________________________________________________________________________ UpdatedBy: CJD04/27/22 SCHEMATIC Well: Whiskey Gulch 1 PTD: 221-046 API: 50-231-20079-00-00 PERFORATION DETAIL Zone Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status T10 2,064’ 2,078’ 1,976’ 1,990’ 14’02/17/22 Open T14A 2,890’ 2,910’ 2,653’ 2,669’ 20’02/16/22 Isolated T18 3,373’ 3,381’ 3,045’ 3,053’ 8’01/11/22 Isolated T48 4,498’ 4,518’ 3,965’ 3,981’ 20’12/28/21 Isolated T48 4,544 4,564 4,003 4,019 20’12/29/21 Isolated T65 6,137’ 6,161’ 5,313’ 5,333’ 24’12/27/21 Isolated T65 6,143’ 6,155’ 5,319’ 5,331’ 12’12/22/21 Isolated OPEN HOLE / CEMENT DETAIL 10-3/4”Est. TOC @ Surface (100% excess) Returns to surface (8/12/21) 7-5/8" 9-7/8” hole: 333bbls 12.0ppg Type I-II lead cement followed by 30bbls 15.8ppg Type I-II tail cement. No losses. 10bbls spacer back to surface (40 bbls spacer pumped). Volumetric ToC based on spacer returns = ~750’ MD. CBL on 8/29/21 shows ToC TOC @ ~1430’. 4-1/2”TOC @ 7,404 (Tagged) CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 10-3/4”Surf Csg 45.5 L-80 DWC/C 9.950”Surf 1,501’ 7-5/8"Int. Csg 29.7 L-80 CDC 6.875”Surf 7,702’ 4-1/2"Abandonment Lnr 12.6 L-80 IBT 3.958”7,538’10,268’ JEWELRY DETAIL No.Depth MD Depth TVD ID OD Item 1 1,220’1,215’6.875”9.950”7-5/8” Swell Packer 2 2,790’2,571’CIBP 3 3,180’2,888’CIBP 4 3,630’3,254’7-5/8” Composite Bridge Plug (magnum) 5 4,790’4,205’7-5/8” Composite Bridge Plug (magnum) 6 7,538’6,640’1.875”4.500”Halliburton BHKA Disconnect Tool Activity Date Ops Summary 7/30/2021 On Seaview Pad, cont to RD lights, spool up cords and prep mods for tear out. RD Handy Berm, sent half the night crew to Whiskey pad to lay out felt, liner and rig mats. Crane on location at 07:30 and first truck. Tore out boiler skid, lowered pit roofs. Spotted crane and removed clam shell.;More trucks at 09:00, tore out catwalk, aux fuel tank, pump skid #2, pit #3, pump skid #1, picked centrifuge off it's stand then picked choke house off outriggers. Tore out gen skid, pit's 2 and 1 and poorboy degasser skid. Layed derrick down. Transported oversize loads to Whiskey pad.;Tore out HPU skid, lowered dog house and tore out same. Spotted 2nd crane, removed derrick house and layed down windwalls, Picked iron roughneck off floor and layed down V door windwall. RU and picked derrick off carrier, picked carrier off sub, picked sub off pony walls. Loaded pony walls and;transported all to Whiskey pad. Offloaded and set pony walls, staged cranes and set sub on pony walls, centered up over wellhead. Stood V door wall, flew iron roughneck to rig floor. transported carrier to Whiskey pad.;Set carrier on sub, set and pinned derrick on carrier, stood derrick windwalls and set derrick house. Set HPU skid, gen skid, doghouse/water tank. Raised doghouse and start RU of that. Stacked rig mats on Seaview pad, clean up liner with vac truck, cut and dispose of liner/felt.;Cont RU air lines and electric to doghouse, install lights on roof tops, hook up jumper hoses and electric cords to pits and pump skids, set service shacks, powered up gen skid and got rig lit up, prepped and stood mast, raised all three pit roof's, raised vac degasser in pit 4, took on rig water. 7/31/2021 Install equalizer lines between pit modules, set clam shell and choke house with crane, set poorboy degasser skid, aux fuel tank and boiler skid. RD office trailers and change shack on seaview pad, transport those to whiskey pad.;Sleeper trailer took out a low hanging phone line on old sterling highway. CCI Supervisor and DOT were notified. Trailer height was lower than max permitted height. Set centrifuge on stand, spotted the 4 trailers, change shack and shop.;Set bang board and gen set, installed vent line on poorboy degasser, stood degasser vessel and RU same, brought in rig loader and BOP's on cradle. Wired in and powered up trailers. Handy Berm bermed in entire rig footprint.;spooled drill line on drum, bridled up and scoped up derrick, set upright water tank, installed standpipe manifold, hung lower torque tube, installed "T" bar and turnbuckles, hung torque bushing, staged topdrive on catwalk and worked to rig floor.;Pinned topdrive to blocks and removed cradle, Installed new bushings in extend arm pin eyes, staged diverter equipment for RU, organized yard and mud dock, changed topdrive swivel and gear box oil. Installed service loop and kelly hose.;Installed HP jumper from pump to sub, installed suction lines from pits to pumps. Set hurricane vac unit.;Changed pump #2 back to 5 1/2" swabs/liners, RU centrifuge and removed shipping blocks, installed shaker slides, hung rig tongs, staged subs, XO's and safety valves on rig floor, set wear ring/test plug in wellhead, RU iron roughneck HPU and function tested same.;Bump test agitators and hoppers, RU Pason weight indicator and depth tracker. 8/1/2021 Installed PVT sensor in upright water tank, RU electric choke and function tested, Obtained RKB’s, Installed DSA, spacer spool, diverter T, annular, flow riser and knife valve.;Torque up diverter bolts, installed vent line out Drillers side of catwalk, bolted and anchored same, staged well on diverter signage. Re-shimed topdrive extend arms, replaced bent load collar adjusting screw on offside of topdrive, rebuilt HCR for spare,;replaced the raising cylinder on iron roughneck and top mounting plate. Received 30 yard dumpsters, checked end play on quill shaft and gear box back lash on topdrive. Cont hauling rig mats off seaview pad.;Cont hauling last of rig mats off seaview pad. Installed flowline to shakers, hung bales and elevators, installed hyd fittings on annular and tied in koomey lines, circulated water through charge pumps, hoppers, gun lines and checked PVT alarms. Oil change on changeshack gen.;Cont rig acceptance checklist, cont testing PVT alarms in pits, RU gai-tronics, function test trip tank pump and mud pumps, Changed out Drillers side hyd winc h cable. 8/2/2021 PU 4 1/2" test joint and set in annular, function tested knife valve and annular, LD test joint, function tested eaton brake high and low, RU skate house and function tested catwalk/skate, set mud pump popoff’s at 3400 psi, checked pulsation dampeners, cont cleaning and disinfecting rig modules.;Got comm’s up and running. Sent all hands getting off tour for covid testing, all hands coming on tour also tested. Had CCI rig support go in for testing. Four rig hands tested positive, only one with symptoms. Painted diverter vent line. Shipped out Baker, Weatherford and Yellow Jacket tools.;Sent CCI Rep to Seaview Pad, to decontaminate electrical room front door, door knob and lock keypad (used for sending reports last couple days), organized pad to make room for incoming surface casing, walked entire berm of pad to repair any loader or truck tire ruts created during rig up.;Completed PM's on iron roughneck, rig hydraulics, catwalk, boiler, rig floor hyd winches, draw works brakes. Disinfected and weekly inspected company trucks, prep to test spare HCR's and manual valve. 8/3/2021 Test two HCR's and one manual valve (spares) at 250/3500 psi. cont working rig acceptance checklist, prep spot for casing rack, clean and organize HPU connex and pump rooms.;Sent two hands to replace blank cap with cap/valve on 4" conductor outlet on Seaview 9. Received total 42 joints 10 3/4" surface casing, including shoe track, pulled protectors and drifted same at 9.87" , re-installed protectors. Received landing joint/hanger and two 13 1/2" tri-cone bits;with bit breaker. Power washed rig floor, A legs, inner windwalls, draw works, pump rooms and mud dock area. Troubleshot Pason system.;Cont troubleshooting Pason, CCI removed plywood sound barrier from south fence on Seaview pad. Set up containment next to pit 3 to park dragon wagon in while loading cuttings or mud. Pressure washed in cellar/sub base.;Disinfect throughout the rig, handrails all equipment controls and crew van, inspect and PM crown, fuel camp and changeshack gens, fuel loader and disinfect cab and ladder. 8/4/2021 Disinfected change shack and crew van then sent night crew home early to minimize exposure to new crew coming on at noon, received surface centralizers, loaded rig mats and shipped to CCI yard, loaded two additional empty trailers with rig mats for shipping later. Tool Push did walk through with;fresh crew, reviewed things to do list.;Reviewed rig acceptance checklist, checked crown saver, CO rod wash alarm sensor pump #1, staged DP bunk in yard, set long pipe racks at catwalk, racked and strapped 86 jnts 4 1/2" drill pipe and 17 jnts HWDP. MU choke shock hose on rig floor, MU gas buster inlet hose from choke manifold.;Removed surface casing protectors and strapped same, troubleshot and resolved Pason wireless channel issue. Completed rig acceptance checklist. With test plug in wellhead filled stack with water to check for leaks, knife valve leaked, tightened that up, vac'd out stack,;PU 4 1/2" joint and set in annular, function tested diverter again to check knife valve, 3 second open time, LD jnt DP. CCI transported bed truck to Nikiski yard. Installed mast hyd cylinder covers. 18 n (LAT/LONG): evation (RKB): 50-231-20079-00-00API #: Well Name: Field: County/State: Whiskey Gulch 1 Whiskey Gulch Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: HEC 169 Job Name:211-00056.04 Whiskey Gulch 1 Drilling Spud Date: 8/5/2021 On covid stand-down, Made and installed splash skirt under rotary table for flow riser, trimmed and cleaned up liner and felt around rig foot print, installed secondary weight indicator on offside of derrick, mounted Quadco horn and light cluster in cellar area of sub, cleared spot on drillers side;of catwalk for cement silo and compressor, layed out Sperry tools and Yellow Jacket jars for DD selection, held teleconference spud meeting for Whiskey Gulch #1. CCI cleared a spot on location to stage cement bulk truck.;Scrub and clean lube room, load CCI trailer with plywood, valves and felt roll for return to town. 8/6/2021 Sorted through screens in screen connex, organize same, re-located Geronimo anchor block to clear path for cement trucks parking later, received cement silo and compressor, set silo and offloaded one bulk trailer into it, staged second bulk truck/trailer on pad, total surface lead cement;delivered = 300 sacks. Shipped out one trailer of rig mats to CCI yard and one trailer assorted items, work on PM’s, cont cleaning, organizing and sanitizing throughout the rig.;Change oil filters on compressor #2, installed latch on V door gate, organized sub rack, cont PM's and work orders, clean koomey room. 8/7/2021 Cleaned and organized drilling connex and spill connex, fueled portable gens, Weatherford power pack and Halliburton compressor, organized pushers dock, transferred all residual water from pits into pit 9, cleaned and sanitized mechanics truck, shipped two trailer loads rig mats to Swanson River;Tyler pad for staging. Sent AOGCC notice for upcoming diverter function test Monday afternoon, notified all service reps to get covid tested and prep to possibly spud Monday evening.;Scrubbed roof tops of pits, PM'd gen #2 and changed oil filters, set the 14" ID wear ring and removed run tool, scrubbed pit walls between pit mods, PM'd traveling blocks, primed various items for paint. Inspected magnaloy coupling on rig's HPU, staged rotary mousehole for PU DP, removed gen 1 and 2;radiator guards and cleaned radiators. 8/8/2021 Double checked equalizer line connections between pit mods, prep pits 1 through 7 to accept spud mud, removed box protectors from DP on racks in prep to PU rack back, offloaded 170 bbls spud mud into pits from G&I, set mousehole in rotary table, PU 86 singles, racked back 43 stands 4 1/2" DP.;Set short mousehole, offloaded remaining 173 bbls of spud mud into active, racked and strapped 17 jnts HWDP, PU racked back 8 stands HWDP, jar stand and NM Flex DC's, staged bit on rig floor.;Hauled 0 bbls of solids to KGF G&I Cumulative: 0 bbls Hauled 0 bbls of fluid to KGF G&I Cumulative: 0 bbls Hauled 0 bbls of cement G&I Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/9/2021 Got Quadco Rep and Mud Engineer covid tested and to the rig along with GeoLog. Quadco re-located one set of lights and horn to outer edge of pit 3 then tested all audio/visual gas alarms with no issues. GeoLog RU gas trap and umbilical, then started troubleshooting comm's in their unit.;Rig crew performed diverter function test with 4 1/2" jnt and took measurements of vent line and nearest ignition source, then performed drawdown test. Functioned flow and PVT alarms. Witness of diverter test waived by AOGCC Jim Regg at 09:58 on 8-9-21.;Filled hole with 24 bbls spud mud and had no leaks, PU johnny whacker, RIH and tagged at 135’ RKB while dusting spud MW up to 9.0 ppg. LD johnny whacker and single jnt, CCI troubleshot hurricane vac and got that running. Staged BHA components at catwalk.;PU motor w/1.5° bend, MU 13 1/2" HDBS tricone bit jetted w/4 x 16's, MU DM collar and scribed with an RFO of 126.98°, MU DGR,EWR, PWD, HCIM, ALD, CTN, HOC collars, XO's and topdrive. Plugged in and downloaded MWD, lined up and shallow pulse tested tools, held PJSM and loaded sources. MU stnd HWDP.;MU topdrive, started pumping at 460 gpm-742 psi, 42 rpm-2673 ft/lbs on bottom torque, drilled from 135' to 248', wob 12K, 100 ft/hr ROP. At 135' increased pump rate to 500 gpm- 960 psi, 128 ft/hr ROP, MW 9.2/vis 216, ECD's at 9.4 ppg, BGG 1 units. CBU at 248'. P/U-36K S/O- 37K ROT-35K;POOH w/ 2 stds. of HWDP for first BHA stage, and RIH w/ flex collars. No issues w/ trip or fill on bottom.;Cont. drilling 13.5" hole F/248'-T/400' GPM-500 SPP-1000 psi Diff-140 psi RPM-60 TQ-3K WOB-14 Max gas 10 units ECD-9.6 ppg P/U-36K S/O-37K ROT-35K.;Crew change. Cont. drilling 13.5" hole F/400'-T/430' GPM-505 SPP-1050 psi Diff-150 psi RPM-62 TQ-3.5K WOB-16.5 Max gas 10 units ECD-9.63 ppg P/U-39K S/O-42K ROT-42K.;POOH w/ 2 stds. of HWDP for second BHA stage, and RIH w/ jar std. and std. #5. No issues w/ trip or fill on bottom.;Resumed drilling 13.5" hole F/430'-T/654' GPM-508 SPP-1186 psi Diff-130 psi RPM-61 TQ-3.1K WOB-16K Max gas 26 units ECD-9.45 ppg P/U-39K S/O-41K ROT-40K. Started mixing 1st new batch of 6% KCL PHPA mud. Distance to well plan: 1.56' 1.53' High .32' Left.;Hauled 40 bbls of solids to KGF G&I Cumulative: 40 bbls Hauled 10 bbls of fluid to KGF G&I Cumulative: 10 bbls Hauled 0 bbls of cement G&I Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/10/2021 Cont directional drilling 13 1/2" surface hole from 654’ to 864'. Rot wob 15K, 506 gpm-1212 psi, 64 rpm-3400 ft/lbs on bott torque, 64 ft/hr ROP. Sliding wob 14K, 559 gpm-1390 psi, 107 psi diff, 5-30 ft/hr ROP. MW 9.2/vis 212, ECD's at 9.6 ppg, BGG 7 units, max gas 24 units, Started build at 803'.;Cont drilling from 864' to 987'. Sliding wob 16K, 557 gpm-1356 psi, 90 psi diff, 28 ft/hr ROP. Rot wob 16K, 555 gpm-1478 psi, 57 rpm-4482 ft/lbs on bott torque, 45 ft/hr ROP, MW 9.2/vis 242, ECD's at 9.5 ppg, BGG 17 units, max gas 39 units. Mad passed slide intervals, building at 3°/100'.;CBU twice at 550 gpm-1350 psi, 60 rpm-3600 ft/lbs off bott torque, obtained survey and flow checked. Well static.;Pulled up hole on elevators from 987' to 309' with no issue. Up wt 55K.;Serviced rig and topdrive, greased crown, blocks, draw works and brake linkage. Cleaned suction screens on mud pumps.;TIH on elevators from 309' to 927', MU topdrive, filled pipe, washed to bottom at 987' while starting a 20 bbl nut plug condet sweep around.;Cont. directional drilling 13.5" surface hole building at 3° per/100' F/927- T/1174'. P/U-56K S/O-58K ROT-57K GPM-550 SPP-1550 psi Diff-100 psi RPM-70 TQ-5.2K WOB-20K max gas 30 units ECD-9.6 ppg. Finished 1st batch of new 6% KCL PHPA mud.;Crew change, held PTSM outside. Cont. directional drilling 13.5" hole, building at 3° per/100' F/1174' to current depth of1397'. P/U- 58K S/O-58K ROT-58K GPM-555 SPP-1524 psi Diff-93 psi RPM-74 TQ-5.2K WOB-20K max gas 46 units ECD-9.63 ppg. Distance to well plan:11.96' 11.96' High 2.67' Right.;Hauled 180 bbls of solids to KGF G&I Cumulative: 220 bbls Hauled 330 bbls of fluid to KGF G&I Cumulative: 340 bbls Hauled 0 bbls of cement G&I Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs Cont directional drilling 13 1/2" surface hole from 654’ to 864'. 8/11/2021 Cont directional drilling 13 1/2" surface hole from 1397' to TD at 1510' md/1488' tvd. Rot wob 20K, 556 gpm-1496 psi, 70 rpm-5239 ft/lbs on bott torque, 30-40 ft/hr ROP, MW 9.3/vis 212, ECD's at 9.6 ppg, BGG 15 units, max gas 40 units. At TD we are 20.57' high 4.40' right of the line in silty shale.;After obtaining survey, CBU 4 times to reduce mud viscosity from 212 to 78 and clean hole at 555 gpm-1372 psi, 73 rpm-4124 ft/lbs off bott torque. Filled trip tank, shut down and flow check = static. Gave AOGCC notice for upcoming casing run and cementing.;Pulled up hole on elevators from 1510' to 338' with no issue. Had a 12K overpull at 1043' (BHA pulling into a slide, no coal).;TIH on elevators from 338' to 1510' washing last stand to bottom after filling pipe. No issues TIH. Up wt 61K, dwn wt 60K.;Pumped a 20 bbl hi-vis nutplug sweep around at 555 gpm-1429 psi, 74 rpm-4000 ft/lbs off bott torque. Sweep came back 10 bbls early and we had a 50% increase in cuttings, had a max of 39 units at bottoms up, cont to circ until shakers cleaned up. Shut down and flow check = static.;Gave Halliburton e-line 4 hr notice, POOH on elevators from 1510' to BHA at 743', racked back HWDP, jars and NM DC's. Held PJSM and removed sources, plugged in and uploaded MWD data. LD Sperry smart iron, drained motor and LD same. RR bit graded a 1-1 and in gauge.;Clean and clear rig floor while spotting Halliburton e-line unit.;R/U HES E-line unit and tool, RIH to bottom E-line tools w/ no issues, logged OOH w/ E-line tools- GTET, Wave sonic, JLatch, and cabbage head.;P/U & M/U 13.5" cleanout assy. BHA #2 as per Sperry. RIH F/Surface-T/1510', M/U TDS, broke circ. washed last std. to bottom. Had no issues during trip and no fill on bottom. Had calculated pipe displacement. P/U-50K S/O-49K;Pumped 20 bbl Hi-Vis sweep w/ walnut & condet, sweep came back on time w/ a 20% increase in cuttings. Cont. circ. till shakers cleaned up. GPM-550 SPP-1075 psi RPM-70 TQ-4K Gave Weatherford casing hands 3 hr. notice.;Flow checked well (Static). L/D E-Kelley;Held PTSM outside on pad, crew change. Cont. POOH F/1485'-T/Surface, racked back HWDP, jars, & flex collars. Broke out bit, bit sub, & XO. Had no issues during tip out and had correct hole for the trip.;Drained stack, P/U test jt. & wear ring removing tool, pulled wear ring. Cleaned rig floor, changed out elevators, dummy run hanger & marked landing jt. L/D same. Gave HES cmt 4 hr. notice.;Held PJSM w/ rig crew, Weatherford, and DSM. R/U Weatherford casing equip. and loaded 10-3/4" shoe track & casing onto catwalk.;M/U and Baker locked shoe track, tested floats (ok),.Cont. RIH w/ 10-3/4" DWC/C L-80 45.5 ppf surface casing as per run tally F/127' to current depth 242'. Gave well hand 2 hr. notice.;Hauled 141 bbls of solids to KGF G&I Cumulative: 361 bbls Hauled 297 bbls of fluid to KGF G&I Cumulative: 619 bbls Hauled 0 bbls of cement G&I Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/12/2021 Cont PU single in hole with 10 3/4" surface casing from 242' to 1471'. top off string with fill up hose and MU landing joint/hanger. Slacked off and landed hanger, string went to bottom with no issues. Up wt 75K, down wt 63K. Topped off landing joint then RD fill up hose.;MU circ swedge and topdrive, PU 1' off seat and break circ at 137 gpm- 0 psi, RD Weatherford. Staged up to 5 bpm-0 psi, brought plug launcher to rig floor and loaded plugs. Shut down pump, broke off topdrive, MU plug launcher and plumbing to pump truck. Cont circ at 5 bpm-409 psi.;Held PJSM with rig team and cementers, Halliburton loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested lines at 804 low 3500 high, good tests. Halliburton pumped 75 bbls 10.5 ppg Tuned Prime Spacer at 5 bpm-119 to 81 psi, dropped bottom plug and pumped 130 bbls (300 sx);12 ppg Type II lead cement at 4.5 bpm-81 to 120 psi, followed by 74 bbls (360 sx) 15.8 ppg Type II tail cement at 4 bpm-129 psi. Started to overboard Spacer 22 bbls into tail cement. Halliburton dropped top plug, then displaced with 9.4 ppg Spud Mud at 5 bpm 126 to 520 psi. Slowed pump to 2 bpm with;10 bbl to go. Bumped the plug 135 bbls into displacement (calculated 136 bbls). Held 1340 psi (FCP of 540 psi) for 3 minutes, bled off and floats held. Bled back 1 bbl to truck. Had 75 bbls of Spacer returns to surface and 94 bbls lead cement to surface. Added Bridge Maker LCM to lead cement at 2.4;ppsx. Mix water temp 60 deg. Pumped 100% excess on both lead and tail. Lost 0 bbls throughout the job. Did reciprocate string until 39 bbls into displacement, seeing cement at shakers and landed the string. CIP at 14:33, 8/12/21. Washed up, RD and released Halliburton.;Backed out landing joint, pulled it to rig floor and flushed it out. LD landing joint, swapped to 4 1/2" elevators, PU kelly joint and XO, MU packoff run tool and packoff, RIH landed packoff, Wellhead Rep RILD's, POOH LD run tool. Start 4 bolting diverter vent line.;PU johnny wacker and MU on kelly joint. MU topdrive and pumped black water while rotating to flush annular, diverter T and spacer spool. Functioned annular a couple times and re-flushed. Shut down, broke down and LD johnny whacker and kelly joint.;ND diverter vent line, flow line, flow riser, knife valve, RU and removed annular, diverter T , spacer spool, and DSA.;N/U B section on well head, Tested FS seals 250 psi Low 5 min & 3000 psi High 15 min (ok);Staged BOP stack in cradle by catwalk, spotted CCI crane and laid over beaver side, pick and tailed in BOP into cellar area w/ crane, R/D CCI crane. Picked and set BOP's on B section w/ cellar hoists. Started mixing second batch of new 6% KCL PHPA mud and cont. to clean pits 1-3.;Held PTSM outside on pad, crew change. Cont. N/U BOP's, TQ BOP flange to well head, N/U choke & kill lines, removed trolley beams and hung catch pan, installed bell nipple and riser on annular, centered and chained off stack. M/U HYD BOP control lines to BOP. Removed 4" valves on conductor and;Capped. installed flow line to catch pan. Finished cleaning pits 1-3 and cont. working on building 2nd batch of new mud.;Changed out grabber box dies, M/U test jt. to test plug, set test plug, tested BOP controls, M/U TIW & dart valve to test jt. Flooded stack, choke manifold, and test equip. Functioned all valves & rams to purge out air.;Performed shell test 250 psi low and 3500 psi High (ok). Attempted to HYD IBOP w/ no luck, Changing out HYD IBOP at report time.;Hauled 89 bbls of solids to KGF G&I Cumulative: 450 bbls Hauled 402 bbls of fluid to KGF G&I Cumulative: 1021 bbls Hauled 94 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs Cont PU single in hole with 10 3/4" surface casing from 242' to 1471'. p gg p p ppg p dropped bottom plug and pumped 130 bbls (300 sx);12 ppg Type II lead cement at 4.5 bpm-81 to 120 psi, followed by 74 bbls (360 sx)p p pp p g p p ( ) ppg yp p p y( 15.8 ppg Type II tail cement at 4 bpm-129 psi. Started to overboard Spacer 22 bbls into tail cement. Halliburton dropped top plug, then displaced with 9.4 ppgppg yp p p pppppgp ppg Spud Mud at 5 bpm 126 to 520 psi. Slowed pump to 2 bpm with;10 bbl to go. Bumped the plug 135 bbls into displacement (calculated 136 bbls). Held 1340 psipppppp g p pg p ()p (FCP of 540 psi) for 3 minutes, bled off and floats held. Bled back 1 bbl to truck. Had 75 bbls of Spacer returns to surface and 94 bbls lead cement to surface. Cont directional drilling 13 1/2" surface hole from 1397' to TD at 1510' md/1488' tvd. Pumped 100%excess on both lead and tail. Lost 0 bbls throughout the job. p 8/13/2021 Removed test sub from saver sub, removed clamp and broke out saver sub, removed top clamp and changed out IBOP on topdrive quill shaft. Installed clamps, saver sub and test sub. RU test hose and tested both manual and hydraulic IBOP at 250/3500 with no issue. RD test equipment. Staged 100 jnts;4 1/2" DP on racks and tallied same for PU rack back prior to BOP test.;Pulled test plug with test joint to install wear ring, test plug hung up in annular element. Functioned element numerous times but bag would not relax to full open. Did pull test plug out but could not get wear ring down through element. Removed koomey line from closing side of annular, no change.;Re-scheduled BOP test time with AOGCC and Quadco Reps from to 18:00. Received 1 truckload 7 5/8" casing.;Removed flow line, flow riser and drip pan. Unbolted annular cap, RU and transferred to ground level, removed annular element from bowl. Had some protruding rubber between metal blocks on outer bottom edge of element, no significant damage. Cleaned and inspected bowl. No significant cuttings or;rubber debris found. Also inspected all three shakers for cracks or deck rubber wear, received 2nd load of 7 5/8" casing, total 66 jnts. Loaded empty trailers with items to be shipped, shipped out Weatherford equipment. CO valve on hopper #3. Greased and installed new annular element, RU and;installed annular cap, bolted down same. Inserted test jnt and function tested numerous times. Installed drip pan, flow riser and flow line. Chained off stack 4 ways, cleaned up tools etc. Installed test plug, flooded surface lines and stack, functioned valves and rams, purged air. Shell tested at;250/3500, good test. Quadco and AOGCC Reps on location at 18:00 hrs.;Quadco Rep tested all audio/visual gas alarms with no issue and released. Tested BOPE at 250/3500 psi for 5 min each on 4 1/2" test joint. Completed test #1, moved onto test #2, couldn't get a low test. Started trouble shooting and looking for leaks, pulled test plug and changed out dove tail seal;on test plug (had minimal wear). Reinstall test plug, functioned rams multiple time, re-purged out air. Attempted to test against lower rams only and still couldn't get a test. Re-hammered up studs on B section, found small leak on hose manifold valve off test jt. Replaced valve.;Re-tested against lower ram, had good test on low & high, attempted to test against upper rams (low test) noticed fluid leaking by rams down stack. Made decision to open ram cavities and inspect VBR's and door seal.;Held PTSM, crew change. Opened ram cavities, inspected VBR's (ok), Driller coming on tour mentione d they had an issue in the past with rams not closing equally and having more stem showing on one side then the other due to stack not being centered.;Buttoned up rams cavities, functioned upper & lower rams multiple times, seen were upper rams were not closing equally but 3/4" of an inch, re-centered stack with chain binders. Upper rams started closing properly. Proceeded to restart test w/ Test #1. Currently working on test # 7 out of 10.;Hauled 13 bbls of solids to KGF G&I Cumulative: 463 bbls Hauled 157 bbls of fluid to KGF G&I Cumulative: 1178 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/14/2021 Cont testing BOPE at 250/3500 psi for 5 min each and performed draw down test. Had to replace cord on Pason flow paddle.;Drained stack and removed test plug, re-flooded stack and choke manifold, functioned rams to remove air from ram cavities, opened valve on conductor 4" outlet. closed kill HCR.;Using test pump, at low speed, pumped 64.4 gallons to pressure up 10 3/4" surface casing tracking every inch of volume vs pressure to 3000 psi and held 30 minutes on chart. Good test. Bled back 64.4 gallons in 5 gallon buckets.;RD test equipment, installed 10" ID "long" wear ring, turned elevators, lined up CMV's and stack for drilling, closed valve on 4" conductor outlet, closed annulus valves. Loosened 4 way chains on stack, shimmed and leveled up sub/mast, tightened chains on stack.;MU 4 1/2" mule shoe on kelly joint, PU singled in hole 100 jnts DP in 1200' batches and racked back total 50 stands. Staged 22 jnts DP to single in BHA with.;PU Sperry motor w/1.5° bend, MU 9 7/8" HDBS 5 blade PDC bit jetted w/5 x 16's, MU DM collar and IBS, scribed with an RFO of 12.82°. MU DGR, PWD, ADR, ALD CTN and HOC collars. Plugged in and downloaded MWD, shallow pulse tested tools, held PJSM and loaded sources.;P/U and singled in the hole w/ 4.5" DP/BHA #3 F/747'-T/1400'. Had calculated pipe displacement. P/U-51K S/O-50K.;M/U TDS, broke circ. CBU, had soft cmt at 1405', drilled up cmt plugs in correct order, cont. drilling shoe track and 20' of new hole T/1530'. GPM-515 SPP-1730 psi Diff-150 psi RPM-40 TQ-5.5 ECD-9.3 ppg Max gas 15 units. P/U- 59K S/O-53K ROT-57K;Held PTSM and weekly safety meeting, crew change. CBU, Held PJSM on displacing over to 6% KCL PHPA mud. Lined up to and pumped 20 bbl Hi-Vis spacer, followed by 9.0 ppg new 6% KCL PHPA mud. Circ. and conditioned mud for LOT.;Shut down pumps, pulled into shoe, R/U testing equip. Performed LOT to EMW of 14.8 ppg 448 psi. Cont. pumping until 932 psi were leak off was seen. Pumped in .54 bbls and bled back .357 bbls, EMW of 21 ppg. R/D testing equip. Blew down choke manifold and re-lined up.;RIH to bottom. Cont. directional drilling 9-7/8" intermediate hole F/1530'-T/1714', building 3° per/100' to 1975'. GPM-518 SPP-1182 psi Diff-103 psi RPM-60 TQ-5K ECD-9.3 ppg Max gas 22 units. P/U-63K S/O-57K ROT-60K Distance to well plan- 21.88' 21.43' High 4.41' Right;Hauled 3 bbls of solids to KGF G&I Cumulative: 466 bbls Hauled 62 bbls of fluid to KGF G&I Cumulative: 1240 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/15/2021 Cont drilling the 9 7/8” intermediate section from 1714’ to 2114', rot wob 7K, 518 gpm-1131 psi, 60 rpm-4300 ft/lbs on bott torque, 150 ft/hr ROP. Sliding wob 9K, 563 gpm-1488 psi, 147 psi diff, 117 ft/hr ROP. MW 9.0/vis 56, ECD’s at 9.3 ppg, BGG 6 units, max gas 390 units in a sand at 2108’.;Cont drifting 7 5/8” casing and received 534 sx lead cement (more coming tomorrow).;Cont drilling from 2114', to 2545', rot wob 7K, 557 gpm-1621 psi, 80 rpm-7100 ft/lbs on bott torque, 150 ft/hr ROP. Sliding wob 5K, 555 gpm-1535 psi, 182 psi diff, 136 ft/hr ROP. MW 9.0/vis 50, ECD’s at 9.4 ppg, BGG 14 units, max gas 106 units.;CBU twice at 556 gpm-1488 psi, 75 rpm-5600 ft/lbs off bott torque. Obtained survey and SPR's, flow check = static.;Pulled up hole on elevators 17 stands from 2545' to 1490', up wt 78K, dwn wt 64K. Saw 20K overpull at 1720', worked through it again and was clean. Had calculated fill for the trip.;Serviced rig and topdrive, monitored well on trip tank, no loss, no gain.;TIH on elevators from 1490' to 2545' filling pipe and washing last stand to bottom with no issues or fill on bottom. Had calculated pipe displacement for the trip;Pumped a 20 bbl hi-vis nut plug sweep, half way into getting BU had to slow pumps down to 274 GPM due to super fines in the mud and shaker over running. Sweep came back 23 bbls late, probably due to turning down pumps (cuttings slip) . Had a 25% increase in cuttings.;Resumed directional drilling 9-7/8" intermediate section F/2545'-T/2865'. GPM-550 SPP-1600 psi Diff-100 psi RPM-80 TQ-6.7K WOB-8K Max gas 268 units ECD-9.5 ppg P/U-82K S/O-64K ROT-73K;Held PTSM, crew change. Cont. directional drilling 9-7/8" intermediate section F/2545'-T/3102'. GPM-555 SPP- 1675 psi Diff-200 psi RPM-80 TQ-7K WOB-6-8K Max gas 64 units ECD-9.5 ppg P/U-87K S/O-67K ROT-75K;Cont. directional drilling 9-7/8" intermediate section F/3102'-T/3163'. Pumped 20 bbl Hi-Vis w/ walnut. Resumed drilling ahead while pumping sweep around. Sweep came back 11 bbls early, w/ a 25% increase in cuttings.;Lost swab in MP #1, shut down pump and changed out swab while circ. w/ MP #2 and working pipe.;Resumed drilling ahead F/3272' to current depth of 3268'. GPM-555 SPP-1730 psi Diff-70 psi RPM-80 TQ-7K WOB-6-8K Max gas 36 units ECD-9.59 ppg P/U-88K S/O-67K ROT-75K Distance to well plan: 9.06' 4.46' High 7.88' Right.;Hauled 143 bbls of solids to KGF G&I Cumulative: 609 bbls Hauled 442 bbls of fluid to KGF G&I Cumulative: 1,682 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs Cont. pumping until 932 psi were leak off was seen. yy g g followed by 9.0 ppg new 6% KCL PHPA mud. p . Performed LOT to EMW of 14.8 ppg 448 psi. y ppg Cont drilling the 9 7/8” intermediate section from 1714’ to 2114', 8/16/2021 Cont drilling the 9 7/8" intermediate section from 3268' to 3535', rot wob 6K, 55 gpm-1843 psi, 80 rpm-7744 ft/lbs on bott torque, 129 ft/hr ROP. MW 9.1/vis 58, ECD's at 9.5 ppg, BGG 13 units, max gas 81 units. Received another 266 sacks lead cement, staged 22 jnts DP for PU.;CBU twice at 556 gpm-1659 psi, 80 rpm- 6936 ft/lbs off bott torque. Obtained survey, SPR's and flow checked (static).;Pulled up hole from 3535' to 2540', up wt 99K. Pulled 20k over or tight spots at 3176'-3123'-2990'-2959'-2929'-2875'-2766'. Had to MU topdrive and backream at 2632' as it would not clean up on elevators.;At 2540' MU topdrive and CBU at 563 gpm-1580 psi, 80 rpm-6200 ft/lbs off bott torque. At bottoms up had 10% increase in fine heavy cuttings, once shakers cleaned up shut down for rig service. Serviced rig and topdrive.;PU singled in hole with 22 jnts 4 1/2" DP from 2547' to 3351', down wt 63K, then ran in 2 stands to 3477'. MU last stand and topdrive, filled pipe and washed down with +/- 4' of fill.;CBU followed with a 20 bbl hi-vis nutplug sweep at 552 gpm-1605 psi, 80 rpm-6275 ft/lbs off bott torque. Had 25% increase in fine heavy cuttings at bottoms up, 10% with sweep to surface.;Resumed drilling 9 7/8" hole from 3535' to 3841', rot wob 7K, 555 gpm-1934 psi, 80 rpm-7519 ft/lbs on bott torque, 140 ft/hr ROP, MW 9.2/vis 65, BGG 13 units, max gas 110 units.;Cont. directional drilling 9-7/8" intermediate section F/3841'-T/ 4279', Pumped 20 bbl Hi-Vis sweep @ 4030', sweep came back 84 bbls early w/ a 20% increase in cutting. GPM-550 SPP-1950 psi Diff-200 psi RPM-80 TQ- 8.6K WOB-8K Max gas 103 units ECD-9.65 ppg P/U-109K S/O-78K ROT-91K;Held PTSM, crew change. Cont. directional drilling 9-7/8" intermediate section F/4279'-T/ 4587'. GPM-550 SPP-2050 psi Diff-200 psi RPM-80 TQ-9K WOB-7-10K Max gas 103 units ECD-9.5 ppg P/U-116K S/O-80K ROT-96K;Circ. till shaker cleaned up. GPM-550 SPP-1825 psi RPM-80. Flow check (static), Got SPR's.;POOH on elevators F/4587' to current depth at report time 3644'. Distance to well plan: 10.77' 4.2' High 9.91' Right.;Hauled 181 bbls of solids to KGF G&I Cumulative: 790 bbls Hauled 424 bbls of fluid to KGF G&I Cumulative: 2,106 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/17/2021 Cont pulling up hole for wiper trip to shoe, from 3644’ to 1735’. Pulled 25 to 30K over at 3644'-3514'-2365'-2322'-2253'-2069'-2004'-1970' but able to work through on elevators and clean them up.;At 1735' MU topdrive and CBU with BHA outside surface shoe. 548 gpm-1465 psi, 80 rpm-5347 ft/lbs off bott torque. Shut down and pulled up into shoe parking at 1483'.;Shut down rig gen, Hilcorp Electrician changed out 3 electrical plugs and receptacles on topdrive HPU, fired up rig gen and serviced rig and topdrive.;TIH from 1483' to 2930' and set down 3 times. MU topdrive, filled pipe, washed and reamed down to 2973', worked stand with no pump/rotary and was clean. Cont TIH and had to work tight spot at 3424' on elevators, at 4461' had to MU topdrive, fill pipe and washed/reamed to bottom at 4587'.;CBU at 505 gpm-1762 psi, 80 rpm-9000 ft.lbs off bott torque. Put 20 bbls low vis low weight pill on vac truck, built 20 bbls hi vis hi weight pill in pill pit. At bottoms up hole unloaded heavy fine sand, 50% increase. Pumped tandem sweep around and had 10% increase to surface. 18 bbls early.;Made hook and resumed drilling intermediate from 4587' to 4776', rot wob 9-10K, 557 gpm-2000 psi, 80 rpm-10,000 ft/lbs on bott torque, 110 ft/hr ROP, MW 9.2/vis 57, BGG 23 units, max gas 74 units.;Cont drilling from 4776' to 5222'7-10k WOB, 559 gpm 2190 psi, 80 RPM, 9.8 - 11k torque on bottom. 74 ROP 9.2 ppg MW, 15 units BGG 212 Max Gas units;Cont Drilling from 5222' t/ 5575' 8-10k WOB 555 GPM 2250 psi 80 RPM 8-11k tq on 9.2 ppg MW 9.67 ppg ECD, Distance to plan 3.84' 3.78' high .068' right;Circulate bottoms up, shakers cleaned up after bottoms up, flow checked well static slight loss, obtain SPR's and survey;POOH f/ wiper trip f/ 5575' t/5161' hit tight spot Kelly up and work through with pumps;Hauled 158 bbls of solids to KGF G&I Cumulative: 948 bbls Hauled 452 bbls of fluid to KGF G&I Cumulative: 2,558 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/18/2021 Cont pulling wiper trip up hole from 5161' to 4586'. At 5162' pulled 35K over three times. MU topdrive and backreamed from 5194' up to 5134'. Upper BHA coming into a large coal sequence at 4920', bit coming out of a coal and into mudstone. Worked stand with no pump or rotary and it's clean.;Serviced rig and topdrive, crown, blocks, brake linkage and checked driveline bolts.;TIH on elevators from 4586' to 5524' and MU topdrive on last stand. No issues going in hole.;CBU at 553 gpm-2123 psi, 80 rpm-8200 ft/lbs off bott torque. Screens started blinding off well before bottoms up due to fine sand. Reduced pump rate to 360 gpm to keep mud on shakers. Had 50% increase in fine sand at bottoms up. Followed with a 20 bbl hi-vis nut plug sweep and able to increase pump;rate again. Sweep came back 35 bbls early and a 10% increase in cuttings. Made hook.;Cont drilling from 5575' to 5720', rot wob 9-10K, 555 gpm-2225 psi, 80 rpm- 10,000 ft/lbs on bott torque, 70 to 140 ft/hr ROP, sliding wob 8K, 554 gpm-2327 psi, 247 psi diff, 81 ft/hr ROP. MW 9.3/vis 60, ECD's at 9.6 ppg, BGG 7 units, max gas 104 units.;Cont drilling from 5720' to 6084', 544 gpm-2404 psi, 60 rpm-10,250 ft/lbs on bott torque, 70 to 100 ft/hr ROP, MW 9.3/vis 55, ECD's at 9.7 ppg, BGG 15 units, max gas 141 units.;Cont drilling from 6084' to 6340' 555GPM 2400 psi 60 RPM 10-12k tq on bottom Pump # 2 stopped stroking but engine was running, shut down pump and found Rim Pack coupler between engine and pump sheave was wore out;Circulate bottoms up on 1#1 pump, parts on the way from Kenai to fix pump;Make wiper trip f/ 6340' t/ 4460' worked through small over pulls, Pump back together;Service Rig and test mud pumps all checked out;RIH f/ 4460' t/ 6073' had one tight spot had to ream through @ 5764';Hauled 104 bbls of solids to KGF G&I Cumulative: 1052 bbls Hauled 311 bbls of fluid to KGF G&I Cumulative: 2,869 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/19/2021 TIH on elevators from 6239' to 6319' and set down three times. MU topdrive, filled pipe, washed and reamed down to bottom at 6340' at 388 gpm-1503 psi, 80 rpm-11,000 ft/lbs off bott torque.;CBU at 338 gpm-1148 psi, staging up pump rate as shakers allowed to 552 gpm-2302 psi. At bottoms up had a 50% increase in fine heavy sand. Pumped a 20 bbl hi-vis nutplug sweep down drill string. Once sweep exited the bit resumed drilling.;Cont direc tional drilling 9 7/8" hole from 6340' to 6494'. Sliding wob 7K, 559 gpm-2564 psi, 228 psi diff, 45 ft/hr ROP. Rot wob 10K, 558 gpm-2548 psi, 70 rpm-11,900 ft/lbs on bott torque, 50 ft/hr ROP, MW 9.3/vis 63, ECD's at 9.7 ppg, BGG 20 units, max gas 51 units. Sweep back 28 bbls early, 10%;Cont directional drilling 9 7/8" hole from 6494' to 6635', rot wob 7K, 557 gpm-2467 psi, 63 rpm-8251 ft/lbs on bott torque, 60 ft/hr ROP. Sliding wob 4K, 556 gpm-2444 psi, 199 psi diff, 23 ft/hr ROP, MW 9.3/vis 59, ECD's at 9.6 ppg, BGG 10 units, max gas 92 units. Cont dropping inc toward 10-11°;Cont Drilling 9 7/8'' Hole f/ 6635' t/ 6780' 555 GPM 2400 psi 80 RPM 10-16k tq on bottom 9.35 ppg MW Continue dropping 3° - 100 slide drilling having issues with stacking weight rocking pipe back and forth to keep f/ stalling out and packing off;Cont Drilling 9 7/8'' hole f/ 6780' t/ 6940' 555 GPM 2425 psi 60 RPM 10-14k tq on bottom 9.35 ppg MW Slide drilling dropping angle 3° - 100' t/ 11° Slide drilling still stacking weight rocking pipe Distance to Plan 7.47' 7.44' Low .71' Right;Hauled 94 bbls of solids to KGF G&I Cumulative: 1146 bbls Hauled 316 bbls of fluid to KGF G&I Cumulative: 3,185 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/20/2021 Cont drilling 9 7/8" hole from 6940' to 7127'. Rot wob 10K, 553 gpm-2525 psi, 60 rpm-10,850 ft/lbs on bott torque, 50 to 60 ft/hr ROP, MW 9.3/vis 54, ECD's at 9.6 ppg, BGG 15 units, max gas 111 units.;CBU at 555 gpm-2369 psi, 60 rpm-10,264 ft/lbs off bott torque.;Backreamed up the hole from 7127' to 6254' at 548 gpm-2247 psi, 60 rpm-10,600 ft/lbs off bott torque, up wt 178K coming off bottom. No issues reaming through entire drop section. Lined up on low side and shut down pumps, parked string at 6317'.;Serviced rig and topdrive, cleaned mud pump suction screens, installed new cotter key in torque tube turnbuckle pin.;TIH on elevators from 6317' to 7067' with no issue, MU topdrive on last stand, filled pipe, washed/reamed to bottom at 7127'.;CBU at 555 gpm-2389 psi, 60 rpm- 10,394 ft/lbs off bott torque. Didn't have to reduce pump rate any lower than 500 gpm-1965 psi. No significant increase in cuttings. Once shakers could handle 55 gpm made hook to resume drilling ahead.;Cont drilling from 7127' to 7276', rot wob 11K, 557 gpm-2483 psi, 60 rpm-10,972 ft/lbs on bott torque, 73 ft/hr ROP, MW 9.4/vis 56, ECD's at 9.7 ppg, BGG 6, max gas 96 units. Received centralizers.;Cont drilling from 7276' to 7599' 555 gpm 2440 psi 60 rpm 10-14k tq on bottom MW 9.35 ppg ECD 9.66 65 -80 ROP avg;Cont drilling from 7599' t/ 7710' 555 gpm 2580 psi 60 rpm 10-12k tq on bottom 9.4 ppg MW 9.79 ppg ECD MWD failure lost gamma, Perform mode switch no change re attempt lost direction Discuss options with town engineer decision made to pull, Distance f/ plan 24.02' Low .01 Right;CBU obtain sample for mud logger, Flow check well, slight loss, Obtain SPR's;POOH on elevators f/ 7710' t/ 6045' work through tight spots w/ pump and rotary @ 6213' and 6104';Hauled 57 bbls of solids to KGF G&I Cumulative: 1203 bbls Hauled 188 bbls of fluid to KGF G&I Cumulative: 3,373 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/21/2021 Cont POOH on alternate breaks, due to DTF, from 6045’ to 5541'. Had to backream at 6040', 5986' and 5951'. At 5541' pulling good so stopped to level sub and derrick.;Unchained BOP stack in cellar, raised and shimmed under off-side sub base. Quadco Rep on location at 07:00 and tested all audio/visual gas alarms with no issues. Got notification we will call current depth of intermediate section TD (7710');Cont POOH on alternate breaks from 5541' to 1700'. Had to backream at 4238', 3675', 3175', 2261'. Stopped at 1700' with BHA outside surface shoe to CBU. CBU at 546 gpm-1530 psi, 20 rpm-3300 ft/lbs off bott torque. 10% increase in cuttings to surface.;Cont POOH to BHA at 747', racked back HWDP, jars and NM flex DC's. Held PJSM and removed sources, plugged in and uploaded MWD data. LD Sperry directional tools, drained motor and broke off bit. Bit graded at 1-2-WT-G-X-3-No-DTF;Clean and clear rig floor, drained BOP stack and rinsed same, PU 4 1/2" test joint and removed wear ring. Set test plug and RU test equipment.;Test BOPS w/ 4.5'' Test Jt t/ 250/ 3500 psi f/5 min each, State Inspectors Waived Witness, test upper lower and blind rams, annular, CMV 1-15, HCR and man choke and kill, TIW and Dart, Auto and Man IBOP, Mezz kill valve, Electric and Man super chokes, perform drawdown test, Quadco tested gas alarms;Had no fail passes;R/D test equipment, Blow down choke manifold, Pull test plug set wear ring.;P/U Clean out BHA as per Directional driller,;RIH t/ 1494' fill pipe, hole took correct displacement;Slip and cut drilling line;Continue RIH f/ 1494' t/ 6949' Set down 20k Unable to work down had to pump and ream through slide intervals @ 6237' & 6265' No other hole issues hole took correct displacement.;Hauled 31 bbls of solids to KGF G&I Cumulative: 1234 bbls Hauled 124 bbls of fluid to KGF G&I Cumulative: 3,797 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/22/2021 Cont TIH from 6949' to 7515' and set down three times. MU topdrive, filled pipe, washed and reamed down to 7566' at 469 gpm-1256 psi, 60 rpm-8500 to 9000 ft/lbs off bott torque. At 7566' set down again. Washed and reamed down to 7690', PU single, MU topdrive, washed/reamed down to 7710';CBU at 543 gpm- 1867 psi, 80 rpm-11,015 ft/lbs off bott torque, reciprocating string. Had 50% increase in cuttings at bottoms up. Pumped 20 bbl hi-vis nutplug sweep around at 613 gpm-2191 psi, 80 rpm. Sweep back 28 bbls late and 25% increase in cuttings. Shut down and flow checked = slight seepage.;POOH on elevators from 7710' to BHA at 632' with no issues. Racked back HWDP, jars and NMDC's, LD stab, XO, bit sub and bit as one component. Re-run bit graded a 1-2.;Cleaned up rig floor, spotted Halliburton e-line unit and staged their tools.;RU e-line equipment, MU Sonic/Imager tool string, start first RIH at 18:40. Set down at 5290' (10' coal), cont to work tool string, POOH reconfigure tools string, add stabilizers and hole finder nose, RIH 24:00 hrs set down same place 5290' Work tools unable to get down, Log out of the hole to shoe;Out of the hole @ 0500 hrs, Break down tool string components, prep to P/U side wall coring tool string.;Hauled 34 bbls of solids to KGF G&I Cumulative: 1268 bbls Hauled 128 bbls of fluid to KGF G&I Cumulative: 3,925 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs Got notification we will call current depth of intermediate section TD (7710'); Cont drilling 9 7/8" hole from 6940' to 7127' 8/23/2021 Halliburton e-line loaded software, PU and assembled SWC tool string, total length 74'. RIH to 5290' and set down numerous times, decision made to obtain core samples from 4570' up to 1690', total 19 stations.;E-line pulled up hole and obtained core samples at 4570', 4501', 3655', 3475', 3376', 3112', 2915', 2900', 2766', 2646', 2625', 2427', 2259', 2106', 2076', 2071', 2002', 1962' and 1690'. Pulled OOH, broke down /LD tool string, processed and packaged core samples, loaded tool basket, RD and released.;PU 9 7/8" cleanout assembly: RR3 HDBS PDC bit, bit sub, XO, stabilizer sub, RIH with NMDC's, HWDP and jars for a BHA length of 632'. Stopped at 2177' and filled pipe, cont RIH to 7710' Wash and ream through tight spots @ 5163' , 5282', 6194', 7452' Washed last stand to bottom.;CBU 10% increase in cuttings on bottoms up, Pump Hi Vis sweep around 611 gpm 2111 psi no increase in cuttings on sweep return 27 bbls late, flow check well static slight seepage;POOH on Elevators f/ 7710' t/ 647' Stand back and L/D BHA @ 197';Hauled 36 bbls of solids to KGF G&I Cumulative: 1304 bbls Hauled 144 bbls of fluid to KGF G&I Cumulative: 4,069 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/24/2021 L/D Jars and NMFC, Stab bit and bit sub, Give state notice f/ upcoming BOP test;Cleaned and clear floor, drained stack pulled wear ring set test plug, C/O upper rams t/ 7 5/8'' solid body, Flooded stack and surface lines.;Test Annular and upper rams w/ 7 5/8'' test jt t/ 250/3500 psi 5 min each good tests;R/D test equipment, removed test jt and test plug, dummy run landing jt and hanger (20.27') staged centralizers and circ swedge R/U fill up line R/U Weatherford.;PJSM, M/U shoe track and check floats, floats good, Continue P/U 7 5/8'' Casing as per detail t/ 1484' circulate pipe volume 277 gpm 101 psi, continue RIH w/ casing t/ 3848' Circulate pipe volume 250 gpm 184 psi Continue RIH w/ casing t/ 7695' tag fill, M/U circ swedge and wash down t/ 7701' land on;hanger, Stage rate t/ 6.6 bpm 256 psi;Circulate and condition mud f/ cement job;M/U cement head and break circulation with cementers, PJSM with all hands;Halliburton loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested lines at 364 low 4100 high, good tests. Halliburton pumped 40 bbls 10.5 ppg Tuned Prime Spacer at 4 bpm- 316 psi, dropped bottom plug and pumped 333bbls (800 sx) 12 ppg Type I II lead cement at 6 bpm- 254;to 125 psi, followed by 30 bbls (145 sx) 15.8 ppg Type I II tail cement at 4 bpm- 140 psi. Halliburton dropped top plug, then displaced with 9.4 ppg 6% KCL at 5 bpm 140 to 1240 psi. Slowed pump to 3 bpm with 10 bbl to go. Bumped the plug 345.5 bbls into displacement (calculated 349.6 bbls). Held 600;psi (FCP of 1240 psi) for 3 minutes, bled off and floats held. Bled back 2.75 bbl to truck. Started to overboard Spacer 335 bbls into displacing cement. Had 10 bbls of Spacer returns to surface and 0 bbls lead cement to surface. Mix water temp 65 deg. Pumped 40% excess on both lead and tail. Lost 0;bbls throughout the job. Did reciprocate string until swapped to displace and was sticky getting back to hanger CIP at 06:29, 8/25/21. Washed up, RD and released Halliburton.;Hauled 26 bbls of solids to KGF G&I Cumulative: 1330 bbls Hauled 234 bbls of fluid to KGF G&I Cumulative: 4,303 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/25/2021 Cement 7-5/8" casing - job notes on 08/25/2021 report. CIP at 06:29, 8/25/21. Wash up, rig down and release Halliburton cementers. Change out liners on mud pumps to 5";Lay down landing joint and wash top of hanger. Make up running tool and pack-off to joint of DP. Install pack-off and RILDS per Vault wellhead rep. Pressure test pack-off seals / hanger void to 5000 psi for 10 mins - good test.;Install test plug and change out upper rams from 7-5/8" to 2-7/8" x 5" VBRs. Rig down casing handling equipment and bail extensions. Make up test joint and floor valves for BOPE test.;Rig up BOPE test equipment. Flood stack and work out air. Function all choke manifold valves and fluid pack lines. Perform shell test - good test.;Test BOPE 250/3500 psi for 5/5 min each. Test notification sent to AOGCC on 05/24/2021 at 05:21. Test witness waived by Jim Regg on 05/24/2021 at 16:27. All tests with 4-1/2" test joint.;R/D test equipment, Blow down lines, Load BHA on catwalk and P/U Cross overs t/ floor;P/U Directional BHA as per DD/MWD, M/U bit, motor and MWD, Get offsets, Upload MWD and Shallow test string, Load Sources, P/U remaining BHA f/ rack, RIH w/ HWDP f/ Derrick t/ 740';Slip and cut drilling line 52', service rig and top drive.;RIH w/ Drilling BHA f/ 740' P/U 76 singles f/ pipe rack t/ 3093';Continue RIH f/ 3093' t/ 7545' out of the derrick;Circulate bottoms up 250 gpm 2015 psi;R/U and test 7 5/8'' Casing t/ 3500 psi f/ 30 min on chart, Pressure up w/ test plug 3.5 bbls pumped in 3.2 bbls returned, R/D test equipment;Wash and ream f/ 7545' t/ 7614' tag plugs, Drill plugs and float collar t/ 7616' Drill cement t/ 7699' Drilling on float shoe;Hauled 67 bbls of solids to KGF G&I Cumulative: 1397 bbls Hauled 783 bbls of fluid to KGF G&I Cumulative: 5,086 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/26/2021 Continue to drill out remainder of shoe and 20' of new hole F/ 7699' - T/ 7730' MD. 250 gpm, 2100 psi, 50 rpm, 12.5K tor, 5K WOB. 180K up, 95K dn, 125K rot,;Circulate hole clean and rig up to perform LOT. MW in/out = 9.5 ppg;Conduct LOT: 7-5/8" shoe at 7701' MD, 6801' TVD, 9.5 ppg MW in/out, Leak off pressure at 1320 psi - 13.2 ppg EMW. pumped 147 gallons, bled back 90 gallons. Sent LOT data to ODE and received ATP with drilling 6-3/4" Production hole section.;Rig down and blow down test equipment. Line up pits and pumps.;Service top drive and rig floor equipment;Drill 6-3/4" production hole section per DD F/ 7730' - T/ 8105' MD: 375' total, 57.7 fph AVROP, 286 gpm, 2348 psi, 20% RF, 50 rpm, 13-14K Tor, 5-8K WOB, MW in/out 9.2 ppg. ECD 10.9 ppg. 193K up, 100k dn, 134K rot.;Continue Drilling 6 3/4'' Production Section f/ 8105' t/ 8538' 290 gpm 2029 psi, 60 rpm 11-13k tq on, 5-8k WOB, MW 9.2 ppg 10.01 ppg ECD, 72.1 FPH Avg ROP;Continue Drilling 6 3/4'' Production Section f/ 8538' t/ 8913' 290 gpm 2404 psi, 60 rpm 11-14k tq on, 5-8k WOB, MW 9.2 ppg 10.26 ppg ECD, 62.5 FPH Avg ROP Distance to plan 61.07' 61.07' Low 7.54' Right;Hauled 8 bbls of solids to KGF G&I Cumulative: 1405 bbls Hauled 72 bbls of fluid to KGF G&I Cumulative: 5,158 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs p( p) Had 10 bbls of Spacer returns to surface and 0 bbls lead cement to surface. p gg p p ppg dropped bottom plug and pumped 333bbls (800 sx) 12 ppg Type I II lead cement at 6 bpm- 254;to 125 psi, followed by 30 bbls (145ppppp sx) 15.8 ppg Type I II tail cement a p Continue RIH w/ casing t/ 7695' tag fil gj g( e P/U 7 5/8'' Casing as g pp pp p p g p Bumped the plug 345.5 bbls into displacement (calculated 349.6 g Lost 0;bbls throughout the job. gp p p p perform LOT. MW in/out =9.5 ppg;Conduct LOT: 7-5/8" shoe at 7701' MD, 6801' TVD, 9.5 ppg MW in/out, Leak off gp pressure at 1320 psi - 13.2 ppg EMW. 8/27/2021 Continue Drilling 6 3/4'' Production Section f/ 8913' t/ 9037' 290 gpm 2100 psi, 60 rpm 11-14k tq on, 5-8k WOB, MW 9.2+ ppg 12.28 ppg ECD, 82.7 FPH Avg ROP;Pump 9.2 ppg high-vis sweep with walnut at 9037' MD. Sweep back on time with 25% increase in cuttings. Take survey and SPRs on bottom.;Perform wiper trip back to 7-5/8" shoe on elevators. Pull f/ 9037' - t/ 7674' md. No hole issues while pulling.;Perform rig service before running back to bottom. Grease crown, blocks, top drive, drawworks, drive shaft, break linkage and iron roughneck. Pull and clean mud pump suction and discharge screens. Verify pulsation dampener pre-charge on both pumps (750 psi).;Wiper trip back to bottom on elevators. Run in f/ 7674' - t/ 9037' MD. Wash and ream last stand to bottom. 210k up, 105k dn, 142k rot, 290 gpm, 2159 psi, 60 rpm, 14k tq. No hole issues while running in. 6' of fill on bottom.;Drill Ahead f/ 9037' t/ 9470' 286 gpm 2157 psi, 65 RPM 14-16k tq on ,9.2 ppg 10.03 ppg ECD, 71.8 Avg ROP, 5-8K WOB;Drill Ahead f/ 9470' t/ 9777' 290 gpm 2508 psi, 60 rpm 13-16k tq on, 9.2 ppg 10.21 ppg ECD, 51.1 Avg ROP, 5-8k W OB;Drill Ahead f/ 9777' t/ 10028' 290 gpm 2450 psi 60 rpm 14-16k tq on, 9.2 ppg MW 10.22 ppg ECD, 41.8 Avg ROP, 5-8k WOB, Distance to Plan 70.48' 70.48' Low 1.46' Left;Hauled 62 bbls of solids to KGF G&I Cumulative: 1467 bbls Hauled 183 bbls of fluid to KGF G&I Cumulative: 5,341 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/28/2021 Drill Ahead 6 3/4'' Hole Section f/ 10,028' t/ 10,271' TD 290 gpm 2660 psi 60 rpm 14-16k tq on 9.2 ppg MW 10.25 ppg ECD, Distance from Plan 79.05' 77.36' Low 16.28' Right;Circulate bottoms up x 2;POOH f/ 10271' t/ 7675' No Hole issues, Hole took correct fill;Service rig and top drive;RIH f/ 7675' t/ 10271' No hole issues, Wash Last stand to bottom no Fill;Pump Hi Vis Sweep around sweep back on time 10% increase in cuttings, circulate shakers clean, Build and pump Dry Job;POOH f/ 10271' t/ 740';Stand Back BHA, Unload Sources, Download MWD, Clean and Clear Floor;Hauled 34 bbls of solids to KGF G&I Cumulative: 1501 bbls Hauled 51 bbls of fluid to KGF G&I Cumulative: 5,392 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/29/2021 Continue Downloading MWD, L/D BHA as per DD/MWD, Break Bit graded a 8-3 RO Clean and Clear floor;Service rig and trop drive;R/U Halliburton E Line M/U Slim Hole Caliper tool string RIH to bottom Log out of the hole to shoe, POOH, L/D Slim hole caliper string, M/U Sonic Dipole and imager tool string RIH t/ 10261' Tag up Log out of the hole to shoe, POOH L/D Tool String, P/U Side Wall Coring string RIH take 19 core samples;as per GEO, POOH, L/D Sidewall coring tool string, M/U CBL Tool String RIH t/ 7 5/8'' Shoe @ 7701' Log out of the hole, L/D Tool String, R/D Halliburton and release;Clean and Clear Rig Floor R/U to L/D HWDP and Flex Collars f/ derrick;Hauled 17 bbls of solids to KGF G&I Cumulative: 1518 bbls Hauled 158 bbls of fluid to KGF G&I Cumulative: 5,550 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/30/2021 L/D HWDP and Flex Collars from Derrick, clean and clear floor;R/U Weatherford Casing Equipment;M/U Mule Shoe RIH w/ 4.5'' IBTM Liner t/ 2727' M/U Disconnect and X Over;RIH w/ 4.5'' liner on DP f/ 2727' t/ 10261' Set down 10125' Washed remaining jts to bottom;Circulate and condition mud f/ cement job 253 gpm 903 psi, M/U side entry sub and pups;PJSM Cement as per detail, PT Lines 393 psi Low 4700 high, Mix and Pump 25 bbls of 10.5ppg tune prime spacer 4 bpm 120 psi, Pump 123 bbls 15.3ppg PTA Cement @ 5 BPM 75 PSI FCP, Drop Disconnect Dart, Pump 5 bbls 15.3 ppg PTA Cement followed by 15 bbls 10.5ppg Tune Prime Spacer Displace w/ 75 bbls of;Mud plug latched up pressured up t/ 2440 psi and released f/ Liner Shut down and allow to equalize, L/D Cement equipment, Wash up truck CIP 0100 hrs;POOH f/ 7539' t/ 6595' 120k PUW 75k SOW;Drop Wiper Balls and Circulate @ 524 gpm 1334 psi 40 RPM 10-15 bbls of contaminated mud on bottoms up;POOH f/ 6595' t/ 2250' Started L/D Pipe @2464' Vacuuming Wiper Balls through pipe and cleaning threads;Hauled 2 bbls of solids to KGF G&I Cumulative: 1520 bbls Hauled 248 bbls of fluid to KGF G&I Cumulative: 5,798 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/31/2021 POOH L/D 4 1/2'' DP f/ 2250' to surface vacuuming Wiper Balls through pipe and cleaning threads. Clear and clean the rig floor 1.9 bbls over calculated displacement on TOOH;Service crown, blocks, top drive, draw works, brake linkage and drive shaft. Troubleshoot iron ruffneck pipe spinners, clamp operating slower than normal.;PJSM, R/U power tongs, 4 1/2'' handling equipment, ready FOSV and XO, M/U WLEG and RIH with 13 jts 4-1/2”, 12.6#, L-80, IBT kill string to 518', torque to 4000 ft/lbs, R/D power tongs and handling equipment/ R/U to run 4 1/2'' DP;PJSM with on coming crew, M/U XO, 1 jt 4 1/2'' DP, 7 5/8'' casing scraper and XOs to 568', TIH on stands of 4 1/2'' DP F/565'-T/7404', Tagged TOC at 7404', confirmed tag w/ 10K set down. Had calculate pipe displacement for the trip. Summitted 24 hr. BOP notice to AOGCC if need.;Circ. & conditioned mud x2 BU. GPM-550 SPP-1596 psi MW 9.25 ppg;R/U testing equip. Tested casing/abandonment plug T/1700 psi for 30 min on chart. Pumped in 1.86 bbls and bled back 1.86 bbls.;R/D testing equip. CBU while confirming test results w/ drilling engineer. GPM-377 SPP-909 psi MW 9.25 ppg;R/U testing equip. Re-tested casing/abandonment plug T/1700 psi for 30 min on chart due to discrepancies between volume pumped and pressures (Good test). Pumped in 1.78 bbls and bled back 1.78 bbls. Blow down choke, flushed test pump.;Held PJSM on displacing well over to 6% KCL brine w/ rig crew, baroid, CCI, & DSM. Pumped 23 bbl Hi-Vis spacer, followed by 353 bbls of 6% KCL brine w/ corrosion inhibitor, over displaced well by 56 bbls till returning fluid cleaned up. GPM-500 SPP-1446 psi. Flow check (static);POOH L/D 4.5" DP, vacuuming wiper balls through pipe, cleaning and re-doping threads and installing thread protectors F/7398' to current depth 5406'. R/D and released Geo-log hands;Hauled 11 bbls of solids to KGF G&I Cumulative: 1533 bbls Hauled 424 bbls of fluid to KGF G&I Cumulative: 6,222 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs ypp p pg p ppg p Pump 123 bbls 15.3ppg PTA Cement @ 5 BPM 75 PSI FCP, Drop Disconnect Dart, Pump 5 bbls 15.3 ppg PTA Cement followed by 15p p p p ppg @ ppppg y bbls 10.5ppg Tune Prime Spacer Displace w/ 75 bbls of;Mud plug latched up pressured up t/ 2440 psi and released f/ Liner Shut down and allow to equalize, pp RIH with 13 jts 4-1/2”, pppg 12.6#, L-80, IBT kill string Continue Drilling 6 3/4'' Production Section f/ 8913' t/ 9037' p Tested casing/abandonment plug T/1700 psi for 30 min on chart. Pumped in 1.86 bbls and bled back 1.86 bbls. pg p Side Wall Coring string RIH take 19 core samples;as per GEO, g Tagged TOC at 7404', confirmed tag w/ 10K set down. RIH w/ 4.5'' IBTM Liner t/ 2727' Drill Ahead 6 3/4'' Hole Section f/ 10,028' t/ 10,271' TD 9/1/2021 POOH L/D 4.5" DP, vacuuming wiper balls through pipe, cleaning and re-doping threads and installing thread protectors F/5406' to 907' Correct displacement TOOH;Crew change. PTM, continue TOOH L/D 5'' DP to 565'. L/D 5 stands DP in derrick, XOs, 7 5/8'' csg scraper, M/U wear bushing puller, drain stack, S/O and engage WB, BOLDS, pull WB, L/D 2 jts DP to 4 1/2'' kill string at 522';M/U XO pup joint, tubing hanger, C/O to 4 1/2'' tubing elevators, land 4 1/2'' kill string with 8k on hanger, WLEG @ 540.6', WHR RILDS, L/D landing joint. PU 23K, SO 23K, Note: load out and start hauling equipment to SR.;R/U test equipment, attempt to test the 10 3/4'' x 7 5/8'' annulus against swell packer, with the test pump pressure up to 2500 psi, not holding, bled off to 1800 psi in 20 min, swell packer not fully engaged. bleed off pressure, R/D test equipment;Install TWC, PJSM, de-energized koomey, N/D BOPE, removed flow nipple and flow line from annular, un-chained stack, R/D choke & kill lines. Un-bolted stack from multi bowl and moved into position to be picked by crane. Notify AOGCC well work to be completed before required BOP test time.;Moved in dry hole tree & N/U, worked on prepping mud pump and cleaning pits modules for rig move. R/D floor handling equip. Installed pressure gauge on 10-3/4" x 7-5/8" annulus, opened annulus valve, had 200 psi on gauge, bled off pressure (water), cont. to monitor annulus.;Well head hand tested dry hole tree void T/250 psi Low for 5 min and 5000 psi High for 15 min (ok). Pressure tested tree T/5000 psi for 5 min (ok), pulled TWC and installed BPV in tree. R/D bails & saver sub from TDS, cont. working on mud pumps & pits.;Pressure washed rig floor, subs and floor equip. Removed all handling equip and subs off rig floor. R/D choke & kill line.;Crew change, held PTSM. Cont. R/D and prepping for rig move. R/D centrifuge and installed shipping block for travel, R/D, secured and prepped for move -pit module #3, mud pump skids 1 & 2, Gen #3, and gas buster. R/D bleeder and stand pipe manifold, clam shell, and test pump. removed handrails on;catwalk, disconnected accumulator hoses and secured in tray, started R/D Pason cables around rig. R/D Geronimo line. Pressure washed inside and out of stack and installed metal covers. R/D boiler module. Cont. loading out misc. equip and items onto floats. R/D shaker and installed shipping blocks,;started unplugging electrical interconnects around rig, installed doors on mud pump house skids, R/D wireless gas detectors sensors, horns, and lights. Inspected and secured derrick board for scoping derrick, R/D ODS weight indicator, R/D jumper hoses between hopper houses and equalizer;lines between pit modules. Removed cuttings shoots from shakers, lowered degasser into pit #4, R/D hole fill pump, lowered roof on pit module #3. Cont. R/D and prepping rig for move to Swanson river. Released rig from Whiskey Gulch #1 at 06:00 hrs. and moving to Swanson river SRU 241-33B.;Hauled 0 bbls of solids to KGF G&I Cumulative: 1533 bbls Hauled 0 bbls of fluid to KGF G&I Cumulative: 6,222 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs attempt to test the 10 3/4'' x 7 5/8'' annulus against swell packer, with the test pump gqp qp p pressure up to 2500 psi, not holding, bled off to 1800 psi in 20 min, swell packer not fully engaged. gg p j land 4 1/2'' kill string with 8k on hanger, WLEG @ 540.6', Activity Date Ops Summary 11/9/2021 Fluid Pack Whiskey Gulch 01 Pump 1 bbl Neat Meth into 10-3/4 X 7-5/8 Casing. Bumped up from 2000 to 3000psi 7 times, but still never stabalized. Final was 400psi loss in 10minutes (FAIL) Left well with 0/0/0 pressures 11/10/2021 Attempt to get MIT test of 7-5/8" x 10-3/4" annulus with neat meth on WG-01 to 2500 psi. Unable to get passing test. Bled off >500psi in final 30 minutes Fluid pack tubing with Diesel. Left well with 0/0/0 pressures 12/6/2021 Mobilized HAK hot oil truck to location. Hook up pump truck to 4.5" tubing and slop tank to 4.5"x 7 5/8" Intermediate casing. Circulated +/- 10 bbls of 6% KCL. Freeze protect surface pipe with 60/40 Methanol. Rig down hot oil truck. IA gauge showing 0 psi. 12/7/2021 Crews arrive on location. Hold safety meeting . Plow contractor continue to remove snow. Open well vented to atmosphere upon arrival. Mechanical gauges showing 0-30 psi. Tubing, and IA had small drip into containment. Dripped stopped after a minute. Production operators started monitoring and testing IA 7-5/8" x 10-3/4" annulus for gas or pressure build for the past 48 hrs. (no gas, no build),MIRU, Weatherford handling equipment, Spot crane, pump truck, and pipe racks. RIg up 4.5" tubing elevators to main block sling. Pipe tongs function tested and hooked to whip line.,Vault wellhead Rep prepped to pull dry hole tree. Screw into BPV and remove. Performed a visual no flow during this timeframe. Nipple down tree flange and master valve. Latch into Hanger profile with 4.5" IBT pup joint and latch elevators. Back out hanger bolts.,Unseat kill string completion at 6500 lbs on crane. Install bowl and slips. Break and laydown 4.5" IBT joints and place on bunk trailer with thread protectors installed. 13 joints of tubing removed from well. Trickle in 6% KCL to keep hole full for pipe displacement. Load 7-5/8" production casing with 1 bbl 60/40 methanol for freeze protect.,OOH with completion. Rig down and load Weatherford handling gear onto Weaver trailer. Wellhead rep installing new bushings and seals in hanger profile. Make up wellhead hanger adapter and production tree. Spot in open top difuser tank from Rain for Rent and spot for coil N2 blowdown.,wellhead Rep tested tubing hanger adapter void tested to 5000 psi. Install BPV in hanger profile. Hook up hot oil truck to production wing valve. Hydro test tree to 250/5000 psi high. Bleed down pressure to zero. Check for flow. Remove 7" hanger and BPV through tree with T bar and crane. Install night cap and close all wellhead valves. Rig down remaining equipment. Location walk around completed. SDFN. 12/13/2021 Fox Energy crew arrives at facility and obtains permit, TGSM. Warm up CT equipment and crane. Spot heater, light plant and man lift. Break off tree cap and flange up adapter spool. NU BOPE to tree and start BOPE Test against swab. AOGCC waived witness by Jim Regg on 12/11/21 at 15:53.,Function test upper (blind/shear) and lower (pipe/slip) rams. Pressure test upper rams, lower rams, flow cross valves, choke manifold valves and inner reel valve to 250 psi low / 3500 psi high. All tests passed. Secure location and SDFN. 12/14/2021 Fox Energy crew arrives at facility and obtains permit, TGSM. Fire up coil and N2 pumping spread.,Make up BHA including 2-1/8" stinger and 2-1/8" big hole cementing nozzle. Stab on to well and pressure test to 250 psi low / 3500 psi high. Open well and RIH to 1000' while cooling down N2 pump. Come online with N2 down CTxTBG backside at 500 scf/min, treating pressure stabilizes at 1500 psi. After 25,000 scf pumped begin to get returns through CT to tank.,RIH regulating speed to maintain a treating pressure of 1500 psi @ 500 scf/min. After 100 bbls of returns taken increase rate to 1500 scf/min to establish treating pressure of 2000 psi. Continue to RIH and park at 7400'. After 320,000 scf of N2 is pumped and 250 bbls of returns taken POOH and park at 6800' due to volume of N2 remaining.,400,000 scf of N2 pumped and ~320 bbls of fluid returns taken. POOH. Final treating pressure of 2850 psi was trapped on well. RDMO. 12/15/2021 Performed MIT IA (7-5/8'x10-3/4'). Did not pass. Bled IA to zero psi after failing MIT and it built back to 480psi. RDMO Initial pressures: Tbg-2420 psi IA-120 psi OA-0 psi 12/16/2021 TBG PSI 2420 I/A PSI 360 12/17/2021 TBG PSI 2420 I/A PSI 310 12/18/2021 TBG PSI 2420 I/A PSI 290 12/19/2021 TBG 2420PSI IA 260PSI 12/20/2021 TBG 2420 IA 190 (added new tubing and gauge above grading) Ambient temp 26F n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: Whiskey Gulch 1 Whiskey Gulch Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name:211-00056.05 Whiskey Gulch 1 Completion Spud Date: 12/21/2021 YellowJacket E-line arrive on location. Conduct JSA and approve PTW. MIRU.,MU GPT and 2-7/8" x 12' perforating gun. GR/CCL to top shot = 15.5'. Bleed WHP down to 1870 psi.,PT lubricator. Have leak at connection above wireline valve. Change out o-ring, Still have leak. Change out lubricator section above wireline valve and o-rings. Still have leak. RD lubricator and wireline valve. Bring back to shop in Kenai to troubleshoot and/or change out wireline valve. SDFG,TBG 1892 PSI Bleed pre perforating I/A 120 PSI TEMP 13F 12/22/2021 YellowJacket E-line arrive on location. Conduct JSA and approve PTW.,MU GPT and 2-7/8" x 12' perf gun. 60 degree phasing, 6 spf PT lubricator/wireline valve to 250 psi low / 2500 psi high. RIH and find fluid level at 6604'. Tag PBTD at 7401'. TBG 1888 PSI IA 100 PSI TEMP 23F,Send correlation data to RE/GEO. On depth. Bleed WHP down to 1855 psi.,Perforate 6143 - 6155' (T65) Initial tubing = 1855 psi, BHP = 2266 psi 5 min tubing = 1855 psi, BHP = 2266 psi 10 min tubing = 1855 psi, BHP = 2266 psi.,POOH. All shots fired. Bull plug is dry. Handover to production to attempt to flow.,Attempt to flow and test T65 zone. Open choke and step down pressure to 1010 psi. Only N2 at surface, no gas. Shut in well and prep to run GPT.,MU and RIH with GPT. Initial Tubing pressure = 1010 psi. Fluid level = 6630'. Pull uphole to perf interval. BHP = 1229 psi, BHT = 99 degF. Tubing press = 1014 psi.,Download 20' gun to 12' gun. MU and RIH with GPT and 2-7/8" x 20' (12' loaded) perf gun. Send correlation data to RE/GEO, confirm on depth.,Re-perf 6143 - 6155'. No Change in surface or downhole pressure. Initial tubing pressure = 1015 psi, BHP = 1249 psi. 5 min pressure = 1015 psi, BHP = 1249 psi. 10 min pressure = 1015 psi. BHP = 1249 psi.,POOH. Gun at surface. All shots fired. Bull plug dry. Laydown lubricator and wireline valve. Install tree cap. Handover to operations. SDFN.,open well to vent as instructed. taking pressure and gas readings at 15-30 minute intervals. 12/23/2021 TBG 20 PSI I/A 0 PSI TEMP 33F 12/24/2021 TBG PSI 465 I/A PSI 0 TEMP 18deg 12/25/2021 TBG PSI 525 A/I PSI 0 TEMP 26 12/26/2021 TBF PSI 695 A/I PSI 0 TEMP 46 12/27/2021 YellowJacket EL arrive on location. Conduct JSA and approve PTW. MU GPT toolstring and PT lubricator. Tubing pressure = 750 psi. IA = 0 psi,RIH with GPT toolstring. Find fluid level at 4204'. BHP at perf interval (6150') = 1524 psi. POOH.,MU 3-3/8" x 24' Perf Gun (low swell charges). PT lubricator to 250 psi low / 2500 psi high. Send correlation data to RE/GEO. confirm on depth.,Perforate 6137 - 6161' (T65) with 3-3/8" x 24' perf gun. Intial, 5, 10, & 15 minute tubing pressures all the same at 762 psi. POOH. Confirm all shots fired. Gun is wet.,MU and RIH with GPT and sample bailer. Fluid level = 4150'. BHP = 1532 psi at mid perf.,Cool down N2 unit. Pump nitrogen down tubing. Fluid starting to move downhole at 1800 psi. Fluid level at 4800'. Shut down N2 unit and trap 2150 psi on tubing. POOH.,Obtain fluid sample from bailer at surface. Laydown lubricator/wireline valve and NU 7" riser above swab valve. SDFN TBG 2150 I/A 260 TEMP 38F 12/28/2021 YellowJacket E-line conduct JSA and approve PTW. MU 7-5/8" composite bridge plug. PT to 250 psi low / 2500 psi high. Tubing pressure = 1800 psi. I/A 125 psi TEMP 37F,RIH with plug. Send correlation data to RE/GEO. On depth. Set plug at 4790' to isolate T65. Tag plug to confirm set. POOH. Bleed pressure down from 1770 psi to 1024 psi.,RIH with 3-3/8" x 20' gun. Send correlation data to RE/GEO. On depth. Perforate T48 from 4498 - 4518'. Initial pressure = 1024 psi. 5 min pressure = 1028 psi 10 min pressure = 1028 psi. 15 min pressure = 1029 psi.,Gun at surface. Confirm all shots fired. Gun is Dry. RIH with GPT. BHP at mid perf (4508') = 1137 psi Tag plug, no fluid in well. POOH. Laydown lubricator. Install night cap. Handover well to production to test zone. 12/29/2021 YellowJacket E-line conduct JSA and approve PTW. Tubing pressure = 20 psi. Call out for N2. MU GPT. I/A 0psi TEMP 37F,RIH with GPT and sample bailer. Find Fluid Level = 4350'. Obtain fluid sample. POOH.,Cool down N2 unit and RU hardline. MU 2-7/8" x 20' perf gun. PT lubricator to 250 psi low / 2500 psi high. RIH with perf gun and pump N2 to pressure up well to 1000 psi. Send correlation data to RE/GEO and confirm on depth.,Perforate T48 zone from 4544 - 4564'. Initial pressure = 1007 psi 5 min press = 1005 psi 10 min press = 1003 psi 15 min press = 1002 psi POOH. All shots fired. Gun is wet.,Handover well to production to test T48 zone.,RIH with GPT and find fluid at 4250'. RIH with 7-5/8" CBP, send correlation data to RE/GEO, confirm on depth. Set CBP at 3630'. Tag plug to confirm it's set. POOH. Pressure well to 700 psi with N2.,RDMO 12/30/2021 TBG 700psi I/A 58psi TEMP 20F 12/31/2021 TBG PSI 700 A/I PSI 20 TEMP 24 1/1/2022 TBG PSI 700 I/A PSI 0 TEMP 14 1/2/2022 TBG PSI 700 I/A PSI 0 TEMP 12 1/3/2022 TBG PSI 700 A/I PSI 0 TEMP 12 1/4/2022 YellowJacket E-line arrive at location. conduct JSA and approve PTW. Having trouble getting tree cap off, get heater trunk on cap to remove. MU 3-3/8" x 8' perf gun. PT lubricator to 250 psi low / 2500 psi high.,Send correlation data to RE/GEO. Confirm on depth. Perforate 3373-3381' (T18). Initial surface press = 759 psi 5 min press = 762 psi 10 min press = 762 psi 15 min press = 762 psi.,POOH and confirm all shots fired. Gun is dry.,Handover to Operations to Test.,Leave well shut-in for the night for pressure build up. Laydown lubricator and tools. Install night cap on top of wireline valves to secure well. SDFN 1/5/2022 YellowJacket E-line arrive. Conduct JSA and approve PTW. MU GPT Toolstring. TBG PSI 44 I/A PSI 0 TEMP 8,Swab valve stem housing worked loose from valve body. Call out for valve repair and fix.,RIH with GPT and tagged plug at 3620'. Seen pressure anomaly ~ 2950 indicating fluid, but pressure reading below 2950' did not indicate fluid level. POOH.,RIH with sample bailer and collect water sample at 3075'. Put water in sample bottle and send to RE/GEO in town.,MU and RIH with GPT and record an Up/Down pass and send to GEO/RE. Fluid level appears consistent below 2875'.,Laydown lubricator. Leave wireline valve on tree, install night cap. Swab valve closed, Master valve open to monitor pressures. SDFN. 1/6/2022 TBF PSI 101 A/I PSI 0 TEMP 14 1/7/2022 TBG PSI 131 A/I PSI 0 TEMP 9 1/8/2022 TBG PSI 160 I/A PSI 0 TEMP 9 1/9/2022 TBG PSI 185 A/I PSI 0 TEMP 9 1/10/2022 YellowJacket E-line and Fox N2 on location. Conduct JSA and approve PTW. MIRU. MU E-line GPT toolstring. TBR 208psi IA 0psi TEMP 15F,PT lubricator to 250 psi low / 2500 psi high. RIH with GPT and find fluid level at 1150'. Start pumping N2 at 1000 scfm. Once surface pressure reaches 2250 psi, reduce rate to 500 scfm. Fluid level dropping ~ 200 ft/20 minutes,N2 rate at 500 scfm. Surface pressure = 2332 psi. Shut down N2 unit once surface pressure = 2500 psi. Fluid level at 2520'.,Wait on surface pressure to drop to 2400 psi. Pressure back up on well to 2500 psi. Fluid level at 2780'.,Wait on surface pressure to drop to ~ 2350 psi. Pressure back up on well to 2500 psi. Fluid level at 3080'.,Wait on surface for pressure to drop to 2400 psi. Pressure back up to 2500 psi. Fluid level at 3375' (perfs at 3373-3381'). Surface pressure = 2474 psi.,POOH with GPT. Close swab and leave surface pressure of 2474 psi on well. Secure well with night cap. LDFN. 1/11/2022 YellowJacket E-line and Fox N2 on location. Conduct JSA and approve PTW. MU GPT and cool down N2 unit. PT lubricator to 300 psi low / 3000 psi high. TBG 1539 IA 80 TEMP 26,Step rate test with N2. Pump at 500 scf, 750 scf, 1000 scf, 1250 scf, 1500 scf, 1750 scf, 2000 scf, 2250 scf, 2500 scf. No indication of pressure breakover. Starting surface pressure at 1520 psi, ending surface pressure of 2800 psi. Have GPT in well at perfs to monitor pressure.,Start pumping N2 at 500 scfm to determine injectivity. Starting surface pressure = 2380 psi, surface pressure declined to 2363 psi. Increase to 700 scfm, pressure starts to increase slowly, up to 2407 psi over 20 minutes.,increase surface pressure to 2600 psi and find rate to keep steady WHP. At 800 scfm, surface pressure is stable at 2584 psi. GPT downhole pressure = 2915 psi. Offline with N2. POOH with GPT. MU 3-3/8" x 8' perf gun. Bleed off surface pressure to 1521 psi.,RIH with 3-3/8" x 8' perf gun. Send correlation data to RE/GEO. On depth. Perforate 3373-3381' (T18) Initial pressure = 1521 psi. 5 min = 1523 psi 10 min = 1525 psi 15 min = 1526 psi,POOH. All shots fired. Gun is dry. Laydown toolstring. Secure well with night cap. LDFN. 1/12/2022 YellowJacket conduct JSA and approve PTW. MU GPT Toolstring. PT lubricator. TBG PSI 1540 I/A PSI 60 TEMP 33,RIH with GPT to just above Perfs at 3350'. Wait for internal temp probe to stabilize. Temp stabilizes at 69 degF. WHP = 1568 psi, BHP = 1760 psi.,Computer on YellowJacket E-line not able to acquire data. Call to change out computer system.,With GPT in well at 3350'. Open choke to drawdown WHP to 1150 psi. Initial: whp = 1150 psi; bhp = 1290 psi; bht = 78 degF 5 min: whp = 1157 psi, bhp = 1290 psi; bht = 78 degF 10 min: whp = 1158 psi; bhp = 1293 psi; bht = 78 degF 20 min: whp = 1159 psi, bhp = 1296 psi, bht = 78 degF,With GPT in well at 3350'. Open choke to drawdown WHP to 1020 psi. Initial: whp = 1020 psi; bhp = 1140 psi; bht = 78 degF 5 min: whp = 1026 psi, bhp = 1145 psi; bht = 78 degF 10 min: whp = 1030 psi; bhp = 1154 psi; bht = 78 degF 20 min: whp = 1032 psi, bhp = 1156 psi, bht = 78 degF,With GPT in well at 3374' (in perfs). Open choke to drawdown WHP to 910 psi. Initial: whp = 910 psi; bhp = 1030 psi; bht = 78 degF 5 min: whp = 918 psi, bhp = 1036 psi; bht = 78 degF 15 min: whp = 924 psi; bhp = 1039 psi; bht = 78 degF 20 min: whp = 926 psi, bhp = 1045 psi, bht = 78 degF Fluid level at 3250',With GPT in well at 3374' (in perfs). Open choke to drawdown WHP to 800 psi. Initial: whp = 800 psi; bhp = 903 psi; bht = 78 degF 5 min: whp = 807 psi, bhp = 911 psi; bht = 78 degF 10 min: whp = 810 psi; bhp = 916 psi; bht = 78 degF 20 min: whp = 814 psi, bhp = 922 psi, bht = 78 degF,With GPT in well at 3374' (in perfs). Open choke to drawdown WHP to 680 psi. Initial: whp = 680 psi; bhp = 775 psi; bht = 78 degF 5 min: whp = 686 psi, bhp = 777 psi; bht = 78 degF 15 min: whp = 691 psi; bhp = 788 psi; bht = 78 degF Fluid Level = 3210',With GPT in well at 3374' (in perfs). Open choke to drawdown WHP to 500 psi. Initial: whp = 500 psi; bhp = 574 psi; bht = 78 degF 5 min: whp = 507 psi, bhp = 581 psi; bht = 78 degF 1/13/2022 TBG 273 psi IA 0 psi TEMP 29 1/14/2022 TBG 441 psi IA 0 psi 1/15/2022 TBG 533 IA 0 1/16/2022 TBG 590 psi IA 0 psi 1/17/2022 TBG 634psi IA 0 psi 1/18/2022 TBG 662 psi IA 0 psi 2/7/2022 TBG PSI 748 A/I 0 2/8/2022 Tbg PSI 748 A/I PSI o 2/9/2022 TBG PSI 748 A/I PSI 0 2/10/2022 TBG PSI 746 A/I PSI 0 2/11/2022 TBG PSI 747 A/I PSI 0 2/12/2022 TBG PSI 744 A/I PSI 0 2/13/2022 TBG PSI 744 A/I PSI 0 2/14/2022 TBG PSI 744 A/I PSI 0 2/15/2022 Conduct JSA and approve PTW. MIRU YellowJacket E-line and Fox N2 equipment.,MU GPT toolstring. PT lubricator to 250 psi low / 2500 psi high. Open well. Tubing pressure = 750 psi. RIH and find fluid level at 1960'. RIH with GPT and park at 3365'.,Flow well with GPT parked at 3365'. Flow well for about 1 hour, then tubing pressure bled down to 0 psi.,RU N2 line to pump in sub and PT to 2500 psi. Pump N2 down well at 1000 scfm and max pressure of 2500 psi. Push fluid to 3200' and keep 2500 psi trapped on well. laydown toolstring and lubricator. Secure well. SDFN. 2/16/2022 YellowJacket arrive location. Conduct JSA and approve PTW. Cable on crane has become entangled and needs to be fixed.,MU and RIH with GPT toolstring. Tubing pressure = 1600 psi. Fluid level is at 3400'. POOH and laydown GPT toolstring.,MU and RIH with 7" CIBP. GR/CCL to top of plug = 16.0'. Send correlation data to town. Confirm on depth. Have a mis-fire. POOH and find bad cap on setting tool. Replace cap on setting tool and RIH with plug. Set plug at 3180'.,Bleed pressure down from 1600 psi to 880 psi. MU and RIH with 3-3/8" x 20' gun. Perforate T14 zone (2890 - 2910'). Initial pressure = 881 psi 5 minute = 884 psi 10 minute = 884 psi 15 minute = 884 psi. All shots fired. Gun is dry.,MU and RIH with GPT. Drawdown well to 664 psi. Fluid level = 3115 psi. 10 minute buildup pressure = 671 psi. POOH with GPT and laydown toolstring. Secure well with night cap.,Drawdown well to 305psi, no gas. Leave shut in for the night. 2/17/2022 YellowJacket E-line arrive. Conduct JSA and approve PTW. Tubing pressure = 523 psi. Drawdown well to 0 psi. Fluid level = 1490'. Obtain water sample.,RU Fox N2 unit and PT to 2500 psi. Pump N2 to push fluid away. Monitor with GPT in well. Push fluid to top perf at 2890'.,MU and RIH with 7" CIBP. Send correlation data to town and confirm on depth. Set CIBP at 2790'. Set down weight on plug to confirm set. Bleed tubing pressure down to 350 psi.,MU and RIH with 3-3/8" x 14' 6spf HSC perf gun. Send correlation data to RE/GEO and confirm on depth. Perf T10 zone (2064-2078') Did not get pressures at surface since SSV tripped. Will get pressures after downloading crystal gauge data. POOH. Shots fired. Gun is dry.,MU tandem downhole gauges on hanger. Open well to gauges at 19:08 on 2/17/22. surface pressure = 762 psi. Send correlation data to RE/GEO to confirm on depth. Set downhole tandem gauges at 2059'. Top of fishing neck at 2049'.,POOH. RDMO. 2/18/2022 TBG 554 psi IA 0psi TEMP 34f 2/19/2022 TBG 512psi IA 55psi TEMP 34F 2/20/2022 TBG 495 psi IA 55 psi TEMP 31 2/21/2022 TBG PSI 738 I/A 55 TEMP 32 2/22/2022 TBG PSI 749 I/A 0 TEMP 34 2/23/2022 TBG PSI 755 I/A 20 TEMP 40 2/24/2022 TBG PSI 755 I/A 20 TEMP 40 2/25/2022 TBG PSI 764 I/A 20 TEMP 40 2/26/2022 TBG PSI 766 I/A 20 TEMP 30 2/27/2022 Tbg-770 iA-20 Temp-35 2/28/2022 TBG = 771 IA = 20 psi 3/1/2022 TBG = 773 psi IA = 20 psi 3/2/2022 TBG = 775 psi IA = 20 psi 3/3/2022 TBG = 776 psi IA = 20 psi 4/3/2022 ARRIVE AT PWL SHOP - GATHER TOOLS AND EQUIPMENT - MOB TO LOCATION A SUSAN DIONNE - JSA - PERMIT - TGSM DEPART SUSAN DIONNE FOR WHISKEY GULCH ARRIVE ON LOCATION - SPOT EQUIPMENT - RIG UP W/L - PT LUB W/ WELLBORE - GOOD RIH W/ 2.5" JDC W/ 5.7" BELL GUIDE TO 2049'KB WT (2 OIL JAR LICKS AT 1500 LBS) COME FREE POOH - OOH W/ STOP AND GAUGES RIG DOWN W/L - SECURE WELL !"# " !#$ %&' () *) +, ) -. ) ) !) !/) 0",)!"" #$%&&'()'*)+, ) /)-./01 - 0 ) #$%&&'()'*)+, 1" ) / 0 *) # *) ( 02) * *)0 +&2*34 , - +&2*- .-.-0, 5'6 ! 07 ! ! ,) ,) 3) 1") 435+! 415+ 6 # ,) '('' '('' & &8 &&(6' )8 9+(28' &'&()'!",3)'(:' :+;68<68(6++- :;68<:(9))6 !/ 789 :, " 7-9 * 789 0,1*0 $!&'& 8='=&'& 9()6 2&(2+ :6 2&8(&6)6&92 ").) ,1) (' /0 . ) ":*7-.9 7 9 415+ 7 9 789 435+! 7 9 -;")8('' 9)('9'('''(''8('' :* 7 9 * -1* 7!/9 - 7 9 8=9'=&'& 9>!1 ?1 7 ''6!@=A6B$!CD 4 1 7(6)(:9 669(8 !1 ?1 7*,* ,'2=&8=&'& 9>!1 ?1 7 ''6!@=A6B$!CD 4 1 7( :')(88 2 )92(:8 !1 ?1 7*&,* ,'8=2=&'& 9>!1 ?1 7 ''6!@=A6B$!CD 4 1 7(2 26(+' ' &99(9 !1 ?1 7*9,* ,'8=&2=&'& 0 7 9 < 789 = 789 435+! 7 9 415+ 7 9 -. 7 9 -. 7 9 0 1" 79 0 3 79 . 79 785>9 -1* 8('' '('' '('' 8('' '('' '(''#&'&()' & &8 &&(6 )8 9+(28 '('' '('' 0-3EA-3 6)(:9 '('& 9&(88 6)(:9 #'('& '('&#26('2 & &8 &&(9+ )8 9+(8' '('& '('& 9>!1 ?1 7*, &'8(29 '(& &'+(&6 &'8(29 #'(& #'('9#(82 & &8 &&(&+ )8 9+(2: '(99 '('2 9>!1 ?1 7*, &)8('8 '('2 +8(&: &)8('8 #'(&: #'('62(68 & &8 &&() )8 9+()8 '(&6 '( 9>!1 ?1 7*, 9&+(&2 '(6& &:(2) 9&+(&2 #'(9) #'(9&'8()2 & &8 &&(') )8 9+(6: '()9 '('9 9>!1 ?1 7*, 9+2(': '(98 &9)( 9+2(': #'(:) #'(262)(6: & &8 &&'(82 )8 9+('& '(2 #'( 9>!1 ?1 7*, 6:2(8) '(+ &))(' 6:2(8) #'()8 #('&92(&) & &8 &&'(2) )8 9+'(2: '(9+ #'(& 9>!1 ?1 7*, :8(6) '(6+ &:&(:) :8(6) #'(2) #(9)&+2(8) & &8 &&'()8 )8 9+'(6' '(: #'(9+ 9>!1 ?1 7*, :2+(:' '(&) &9&(:+ :2+(6+ #'(+9 #(2&9:8(8+ & &8 &&'(:9 )8 9+'('6 '(69 #'(:9 9>!1 ?1 7*, )6(9& '(:8 &6:(8: )6(9 #(6 #&(6&'(2 & &8 &&'(99 )8 98+()6 '(:6 #'(): 9>!1 ?1 7*, 2'(2' '(&: &&:(' 2'()+ #(9) #&(6+68('+ & &8 &&'(& )8 98+(&) '(:+ #'(2: 9>!1 ?1 7*, 2)&(:2 '(:+ &6'(9& 2)&(:) #() #&(8::6(+) & &8 &+(88 )8 988(88 '(:8 #'(8& 9>!1 ?1 7*, () *) +, ) -. ) ) !) !/) 0",)!"" #$%&&'()'*)+, ) /)-./01 - 0 ) #$%&&'()'*)+, 1" ) / 0 7 9 < 789 = 789 435+! 7 9 415+ 7 9 -. 7 9 -. 7 9 0 1" 79 0 3 79 . 79 785>9 -1* 8&:(': '(+) :9('' 8&:('6 #&(&9 #&(8+)'6(66 & &8 &+(&) )8 988(89 (22 #'(6' 9>!1 ?1 7*, 88:(+2 &(8& 98(9) 88:(+& #9(8 #()2)):(9& & &8 &2(): )8 9+'(' 9(9 (:8 9>!1 ?1 7*, +68(+6 6(8+ 9)(9' +68(26 #)(+ (&&2&8(6 & &8 &6(62 )8 9+&(8 9(&+ :(8 9>!1 ?1 7*, ''(6' 2(: 96(6& ''+(86 #() :(+'28+(&6 & &8 &'+()6 )8 9+2(9) 6(&8 &(6: 9>!1 ?1 7*, '2&(92 '(92 96('' '2(': #8(9& &(8'8:'(6: & &8 &'&(2: )8 6'6('8 6()& &&('2 9>!1 ?1 7*, 9&(:8 &(26 9:(2: 9'('6 #&)(86 &(99+'+(66 & &8 +6('' )8 6&(98 9(+8 96(9 9>!1 ?1 7*, +:(6) 6(88 9)( +('+ #92()9 9(22+2'(6+ & &8 8&(+9 )8 6&&(:& 9(6 6+(6 9>!1 ?1 7*, &:8(& )(: 9)(:+ &:(6& #6+(+' 69(62 '9'(8& & &8 2'(9: )8 699(88 &() ))('+ 9>!1 ?1 7*, 9&'(29 8(&: 92()8 9(2 #)9() :)(8 '+'(:2 & &8 :)(9' )8 66)(& &(89 86(2+ 9>!1 ?1 7*, 98&(:9 +(82 98(2+ 9)+(:8 #28()2 )+()& 68(+8 & &8 6'(88 )8 6:+(&9 &()+ '6(+: 9>!1 ?1 7*, 669(8 &(+ 9+(82 6&)(+) #+6(+2 89()& &')(9) & &8 &6(&' )8 62&(2+ &(&6 &)(6' 9>!1 ?1 7*, :')(88 &&(&6 6(6& 68:(:) #9('& +8(6 &)6(+) & &8 ':(2) )8 682('8 (+' 6+()) 9>!1 ?1 7*&, :)+(8& &&('8 6(6 :69(8: #9(:2 9(& 9&9(&: & &8 '8)(8 )8 :'(98 '(&: 29(9' 9>!1 ?1 7*&, )9&(': &6(' 9+(88 )'( #:'(6' &8()2 98'(: & &8 ')2(:2 )8 :)(9 9(&: +2(:8 9>!1 ?1 7*&, )+6()+ &:(29 98(:: ):2(+6 #2'(96 6:(88 692(96 & &8 '62(2 )8 :9&(+8 &(8+ &&9(88 9>!1 ?1 7*&, 2:2()2 &2() 98(+ 26(99 #+(9' )6(:& 6+9(29 & &8 '&:(2 )8 ::('6 &(&8 &:(+' 9>!1 ?1 7*&, 8+(: &+(9 92('6 2)8(8: #&&(86 86(+ :68(&: & &8 ''9(): )8 :2'( 9(9' &8(') 9>!1 ?1 7*&, 88&(8& 9'(82 9:(26 8&9()8 #&9:(2: &')('9 )'9('8 & &2 +8'(: )8 :+(9& &(+9 9&(2 9>!1 ?1 7*&, +6:(:9 9&(69 96(:9 822(') #&:+(') &&+(&6 ):)(6) & &2 +:)(& )8 )9(+' &()+ 96:() 9>!1 ?1 7*&, & ''2(2: 9&(8) 96() +&+(6: #&8&(:& &:9(&: 2'8(8: & &2 +9&( )8 )92(&: '(2) 92+() 9>!1 ?1 7*&, & ')+(9: 9&(:8 96(&8 +8(&8 #9':(26 &22( 2)'()8 & &2 +'8(&: )8 ))'(68 '(62 6&(66 9>!1 ?1 7*&, & 9'(++ 99(96 9:()' & '99('' #9&+(69 9''(86 8&(6' & &2 889(+& )8 )89(:) (2' 66:(+) 9>!1 ?1 7*&, & +&(99 96(6& 92(2) & '89(+& #9:6(9 9&6(&+ 8)9(9& & &2 8:8(6 )8 2')(9& &()6 68'(: 9>!1 ?1 7*&, & &:6(69 96(29 98(99 & 9:(': #98'(:& 962(8: +6(6: & &2 89(:8 )8 2&+() '(2& ::(92 9>!1 ?1 7*&, & 9)(9+ 9:() 9)(8+ & 8:(86 #6')(29 92(28 +):(&6 & &2 8'6(29 )8 2:&(92 (:' ::'(86 9>!1 ?1 7*&, & 92)(8) 9:(:) 9)(: & &9:() #69&(&' 9+:(28& '6(:) & &2 228()& )8 22:()2 '(2: :8:(86 9>!1 ?1 7*&, & 698(6+ 9:(66 9)() & &8:(99 #6:8(8 6&'(9+& ')6(29 & &2 2:(+2 )8 2++(:) '(&& )&()& 9>!1 ?1 7*&, & :''(' 9:(99 9)(99 & 99:(:) #686(': 666(+)& 6(+) & &2 2&:(6: )8 8&9(6& '(9& ):2(9' 9>!1 ?1 7*&, & :)(:6 9:(:& 9)(9: & 98:()9 #:'+(8 6)+(:6& ):('9 & &2 )++('& )8 862(&+ '(9 )+&(+ 9>!1 ?1 7*&, & )&&(+) 9:(62 9)(: & 69:()9 #:9:(:2 6+6(&'& &:('9 & &2 )2&()' )8 82(&: '(& 2&8(:2 9>!1 ?1 7*&, & )8:(6: 9:()& 9)(68 & 68)(68 #:)(8: :+(9'& &):(88 & &2 )6:()) )8 8+:() '(9+ 2)6(+' 9>!1 ?1 7*&, & 26)(2+ 9:(22 9)()& & :9)(9' #:82(89 :69(+& 9:(2' & &2 )+('& )8 ++(: '(&8 8''()+ 9>!1 ?1 7*&, & 8'+(8 9:(29 9)(66 & :8)(+9 #)6(&8 :)8(++& 9))(99 & &2 :+(8+ )8 +69(8) '(8 892(6 9>!1 ?1 7*&, & 82('2 9:()+ 9)()6 & )92(8 #)6'(:' :+9(89& 6)(:8 & &2 :):('' )8 +)2(++ '(&' 829(&) 9>!1 ?1 7*&, & +9&(9: 9:(:+ 9)(:+ & )8)(++ #)))(6: )8(9)& 6))(9+ & &2 :98(6' )8 ++(8' '(2 +'8(+2 9>!1 ?1 7*&, & ++6(:9 9:()& 9)(26 & 292(:6 #)+&(28 )69(&& :)(+6 & &2 :(6' )+ ':(+& '(: +6:() 9>!1 ?1 7*&, 9 '::(+2 9:(:8 9)(9+ & 282(:' #28(2) ))2(2+& :))(+' & &2 686(22 )+ '9+(2+ '(96 +8'(+9 9>!1 ?1 7*&, 9 8(:9 9:(:9 9)(6+ & 898(9+ #26:(& )+&(8)& )2(2+ & &2 6:2(26 )+ ')6(6 '(& '2(9 9>!1 ?1 7*&, 9 2+() 9:()8 9)(22 & 888(') #22'(+2 22(&8& ))2(6) & &2 69(&9 )+ '82(86 '(9) ':&(8) 9>!1 ?1 7*&, 9 &6&(8) 9:(:) 9)(6+ & +9+(62 #2+2(2: 26&(:8& 28(82 & &2 6'9(28 )+ &(6' '(9& '8+(2' 9>!1 ?1 7*&, () *) +, ) -. ) ) !) !/) 0",)!"" #$%&&'()'*)+, ) /)-./01 - 0 ) #$%&&'()'*)+, 1" ) / 0 7 9 < 789 = 789 435+! 7 9 415+ 7 9 -. 7 9 -. 7 9 0 1" 79 0 3 79 . 79 785>9 -1* 9 9'6(+ 9:(:6 9)(:9 & +8+(92 #8&9() 2)2(&& 2)8(22 & &2 922(&: )+ 9)(&9 '(': &:(9) 9>!1 ?1 7*&, 9 9))('2 9:()6 9)(6' 9 '9+()+ #86+(2& 2+(+9& 8+('+ & &2 9:'(68 )+ )'(9& '(&' )(92 9>!1 ?1 7*&, 9 6&2(:: 9:()+ 9)(:2 9 '8+()6 #82:(2& 8)()& 8)+('6 & &2 9&9(8& )+ 86(&8 '(8 +2(& 9>!1 ?1 7*&, 9 68+(6: 9:() 9)(&2 9 9+(+6 #+'(8: 86(68& ++(96 & &2 &+2('& )+ &'8(66 '(9 &99(&+ 9>!1 ?1 7*&, 9 ::(9+ 9:(86 9)()8 9 +'(&& #+&8('8 8))(98& +)+()& & &2 &2'(9 )+ &9&()& '(:6 &)+(6: 9>!1 ?1 7*&, 9 )&(+& 9:(): 9)(6+ 9 &6'() #+:6(+ 8+('+9 '+(:) & &2 &69(9) )+ &:)() '(9) 9':(6' 9>!1 ?1 7*&, 9 )2:()8 9:()9 92('2 9 &+(2 #+8'(89 +)(99 '2'(:2 & &2 &)('6 )+ &8'(+ '(:6 96(+) 9>!1 ?1 7*&, 9 29)(62 9:(62 9)(+) 9 96'()9 # '')()+ +6'(&99 &'('9 & &2 8+(:6 )+ 9'6(9' '(&8 922(9' 9>!1 ?1 7*&, 9 2+8(:) 9:(9' 92(' 9 9+(&: # '99('' +)6(299 2'(): & &2 )&(:2 )+ 9&8('8 '(9' 69(&: 9>!1 ?1 7*&, 9 8)'(9+ 9:(9' 9)(2: 9 66(2 # ':+(' +8+(69 &&( & &2 9:(8& )+ 9:(22 '(99 668(+2 9>!1 ?1 7*&, 9 +&&(89 9:(& 9)(+: 9 6+&(29 # '8:(9) '9(2)9 &2&(9 & &2 '8(+' )+ 92:()2 '(96 686(+2 9>!1 ?1 7*&, 9 +8:(99 9:(&2 9)(+6 9 :69(8' # ()8 '98(9:9 9&9(&' & &2 '8(+& )+ 9++(:9 '(&6 :&'(++ 9>!1 ?1 7*&, 6 '62(&& 96(+2 9)(22 9 :+6(6& # 92()) ')&(2'9 929(8& & &2 '::(&+ )+ 6&9(2 '(: ::)(:+ 9>!1 ?1 7*&, 6 '+(&6 96(+' 9)(+: 9 )6:(&2 # )9(:8 '8)(+89 6&6()2 & &2 '&8(2& )+ 66)(26 '(&' :+&(' 9>!1 ?1 7*&, 6 2'() 96(82 9)(+) 9 )+:() # 8+(&9 '(+69 62:(' & &2 ''&(69 )+ 6)+(++ '(': )&2(&' 9>!1 ?1 7*&, 6 &9&(9' 96(8 9)(+9 9 26)(&6 # &6(+8 9:(''9 :&:()6 & &) +2)('9 )+ 6+9(96 '(' ))&(66 9>!1 ?1 7*&, 6 &+9(8' 96(8 92(' 9 2+)(26 # &6'()6 :8(+)9 :2)(6 & &) +6+(29 )+ :)(:+ '('2 )+2(:6 9>!1 ?1 7*&, 6 9::(69 96()6 92('9 9 862(9+ # &))(99 8&(8+9 )&)(2+ & &) +&9(6' )+ :9+(8& '(&8 29&()6 9>!1 ?1 7*&, 6 62(29 96()2 9)(+8 9 8+8()6 # &+&(&6 &'2(':9 )28('6 & &) 8+)(86 )+ :)9(&) '('2 2)8(') 9>!1 ?1 7*&, 6 62+(6: 96(6: 92(&' 9 +6+(62 # 92(88 &9'(8+9 2&8(82 & &) 82'(:) )+ :8)(6' '(6 8'9('2 9>!1 ?1 7*&, 6 :6()' 96(9: 92(9' 6 '''(2: # 969()2 &:6(2&9 28'(: & &) 866(6 )+ )'+(:& '(8 898(2 9>!1 ?1 7*&, 6 )'9(&2 96(:: 92()2 6 ':()' # 9)+(98 &28(9'9 89('' & &) 82(2+ )+ )9&(9+ '(62 829(': 9>!1 ?1 7*&, 6 ))6(+& 96()+ 92(66 6 '&(96 # 9+:(&9 9'(+69 88(26 & &) 2+(9& )+ )::(9& '(9 +'8(') 9>!1 ?1 7*&, 6 2&)(:) 96(2& 9)(+2 6 :9(' # 6&'(+8 9&:(289 +9&(6 & &) 2)6(+& )+ )28(6: '(66 +69(: 9>!1 ?1 7*&, 6 288(89 9:(82 9:(28 6 &'9(89 # 662('& 9:'()'9 +89(&9 & &) 298(&& )+ 2'&(:) &(: +2+(& 9>!1 ?1 7*&, 6 8:(& 9)(&6 9:('8 6 &:6(+ # 629(9 92)(996 '99(:+ & &) 2(6& )+ 2&2(:2 '(8+ & ':(28 9>!1 ?1 7*&, 6 +&(88 9)('6 9:(9 6 9'6('2 # 6+8(+6 6'&('66 '89(62 & &) )86(+& )+ 2:&(:) '(99 & ':&(&' 9>!1 ?1 7*&, 6 +26(9) 9:(2' 96(+) 6 9:9(8+ # :&6(69 6&2(6+6 99(&+ & &) ):8(2: )+ 222(9 '(:8 & '88(&& 9>!1 ?1 7*&, : '9)('' 9:(+2 9:(') 6 6'9(8) # :6+(+: 6:9('6 89(&) & &) )9&(:6 )+ 8'&(& '(6: & &6(9' 9>!1 ?1 7*&, : '+2(98 9:()8 96(2+ 6 6:9()9 # :2:(9& 628(666 &99('9 & &) )')(6+ )+ 8&)(8) '(:6 & )'(&& 9>!1 ?1 7*&, : :+(6) 9:(:' 96(8' 6 :'6( # )''(28 :'6('86 &89(: & &) :8'(9: )+ 8:(8' '(&+ & +)(96 9>!1 ?1 7*&, : &&(+8 9:(&' 96()6 6 :::(' # )&)(&9 :&+(286 996(:' & &) ::6(&' )+ 82)(8' '(:' & &9&(:' 9>!1 ?1 7*&, : &89(26 9:('2 96(:6 6 )':() # ):(8 :::('6 98:(' & &) :&8(:2 )+ +'(69 '(&9 & &)8('6 9>!1 ?1 7*&, : 96:(9: 96(28 96(:8 6 ):)(9 # )2:(+9 :8'(&96 69:(:9 & &) :'9(: )+ +&:(88 '(62 & 9'9(9' 9>!1 ?1 7*&, : 6')()+ 96()+ 96()+ 6 2')(:9 # 2''(6+ )':('6 68:(+9 & &) 622(+9 )+ +:'('2 '(8 & 998(&6 9>!1 ?1 7*&, : 6)8(6 96(:) 96(28 6 2:2(' # 2&:(') )&+(+'6 :9)(:' & &) 6:&()+ )+ +26(&' '(&9 & 929(6 9>!1 ?1 7*&, : :&+(:2 96(:6 96(+) 6 8'2(2' # 26+()6 ):6(:+6 :82(' & &) 6&2(6: )+ ++8(& '(2 & 6'2(+2 9>!1 ?1 7*&, : :+()9 96(: 96(2) 6 8:8(+6 # 226(96 )2+(66 )98(96 & &) 6'&('+ 2' '&&(9: '(): & 66&(+8 9>!1 ?1 7*&, : ):9(&) 99(+6 96(86 6 +'('' # 2+8(): 2'9(8+6 )8+(6' & &) 922(& 2' '6)() '(9: & 622(62 9>!1 ?1 7*&, : 2:('' 96(& 92(&: 6 +)(2 # 8&9(:& 2&2(826 26'(:2 & &) 9:()' 2' ')+(6: &(&' & :&('& 9>!1 ?1 7*&, () *) +, ) -. ) ) !) !/) 0",)!"" #$%&&'()'*)+, ) /)-./01 - 0 ) #$%&&'()'*)+, 1" ) / 0 7 9 < 789 = 789 435+! 7 9 415+ 7 9 -. 7 9 -. 7 9 0 1" 79 0 3 79 . 79 785>9 -1* : 22)(8& 96('' 92()2 : '&(9+ # 86+('9 2:(&86 2+(2+ & &) 9&:(62 2' '+&() '(69 & :6)()9 9>!1 ?1 7*&, : 89+(8 99(+ 92()2 : ')6()6 # 82:('6 226(+26 866('6 & &) &+8(8& 2' :(9 '(6 & :8(8' 9>!1 ?1 7*&, : +'&(' 99()) 92() : )(6 # +''()9 2+8(96 8+:(8 & &) &2&()' 2' 92(22 '(6' & ))(6& 9>!1 ?1 7*&, : +)9() 99(6: 92(+: : )2()2 # +&:(8 8&(:6 +62('2 & &) &6)(8 2' :+(+& '(6) & ):'(6 9>!1 ?1 7*&, ) '&:(++ 99(&6 92(+ : &+(28 # +:(&2 866(96 +++(8 & &) &&'(2: 2' 8&(&' '(96 & )86()8 9>!1 ?1 7*&, ) '82(92 9&(8: 92(89 : &2(&9 # +2)('+ 8))(:8: ':'()9 & &) +:(9& 2' &'9(+2 '()6 & 28(9 9>!1 ?1 7*&, ) 6+(6+ 9&(6' 92(2: : 9&9(:: #& '''(8+ 88+('8: '&(+: & &) )+(+ 2' &&:(28 '(29 & 2:() 9>!1 ?1 7*&, ) &(62 9&(' 92(:8 : 92:(+2 #& '&:(96 +(9): ::(92 & &) 66(82 2' &62(9+ '(: & 286()2 9>!1 ?1 7*&, ) &2&(9) 9'(26 92(:& : 6&2(+9 #& '68(2) +9&(28: &'2(99 & &) &'(82 2' &)8() &(&9 & 8)(6' 9>!1 ?1 7*&, ) 99)(': &8(:+ 9:(2+ : 689(&) #& '2()+ +:6(6': &)&()) & &) '+2(9) 2' &8+(: 9()9 & 862(+ 9>!1 ?1 7*&, ) 9++(6 &)(6' 9:(6: : :9+(&9 #& '+&(:& +26(22: 98()9 & &) '2)('' 2' 9'8(+: 9(68 & 822('6 9>!1 ?1 7*&, ) 6)'(: &6(96 96(:& : :+6(9: #& ('' ++9(&): 929(2: & &) ':2('& 2' 9&)(+9 9(6: & +'9(2 9>!1 ?1 7*&, ) :&&(&8 &&(98 96(6: : ):(98 #& &8(&) & ''(89: 69'(28 & &) '9+(&8 2' 966('& 9(: & +&2(8' 9>!1 ?1 7*&, ) :89(+' &(': 9:(&) : 2'8()9 #& 66(96 & '&)(++: 688('9 & &) '&&(28 2' 9:+(26 &(&& & +:'(:+ 9>!1 ?1 7*&, ) )6)()8 +() 9:('' : 2)2(:' #& :+(2+ & '6&(98: :6)(+' & &) '')(+ 2' 926(2' &(&+ & +2&(6' 9>!1 ?1 7*&, ) 2'(+ 8('' 96(6 : 8&2() #& 26(&' & ':)(+9: )'2(' & &: ++&( 2' 988(8) &(:: & ++&(8) 9>!1 ?1 7*&, ) 22&(9: :(9' 99(8 : 882() #& 8)()' & ')+(2: )))(:) & &: +2+(92 2' 6'(&+ 6(9) 9 ''()) 9>!1 ?1 7*&, ) 899(+& 6(+ 99(:& : +6)(2 #& +2(6& & '8('6: 2&)( & &: +)8(&6 2' 6&(99 (8' 9 '&)(9& 9>!1 ?1 7*&, ) 8+:(89 (++ 99(: ) ''2('' #& &'2(': & '+(&6: 28)(6' & &: +:8(96 2' 6&&(&2 9(:) 9 '6'(99 9>!1 ?1 7*&, ) +:2(86 '(+6 99(:) ) ')2(22 #& &:(: & ''(&: 862(2 & &: +6+()6 2' 69('' (2' 9 ':&()6 9>!1 ?1 7*&, 2 '+(9+ '(2' 99(+8 ) &8(&9 #& &&9(:' & '8(::: +'2()9 & &: +6(6& 2' 69+(& '(6 9 ')6(+ 9>!1 ?1 7*&, 2 '8('& '(66 9&(+9 ) 88(8 #& &9(&8 & )(2): +)8(& & &: +99(69 2' 662( '(:9 9 '2:(68 9>!1 ?1 7*&, 2 69(6' '(&) 99()& ) &:'(8 #& &98(+) & &6(+&) '&+(:8 & &: +&:(:9 2' 6::(') '(9: 9 '8)()8 9>!1 ?1 7*&, 2 &':('6 +(+: 99(96 ) 9'(8) #& &6)(6' & 9&(2)) '+'(&) & &: +2(82 2' 6)&(2' '(: 9 '+2(68 9>!1 ?1 7*&, 2 &))(8 +(96 9&(88 ) 92(2) #& &:9(68 & 6'(9&) :() & &: +'()' 2' 62'(') ('' 9 '2(8& 9>!1 ?1 7*&, 2 9&+(2 +(&2 99(9: ) 699(9' #& &)'(92 & 62()8) &&(2' & &: +'9(: 2' 622(&9 '(2 9 2(8+ 9>!1 ?1 7*&, 2 9+'(+8 8()2 99(:) ) 6+6(9: #& &)2('' & :6()2) &29(2: & &: 8+)()+ 2' 686(': '(+2 9 &2(: 9>!1 ?1 7*&, 2 6:&(2' 8(:+ 96(+2 ) :::(92 #& &29(6) & )(9) 996(22 & &: 8+'(': 2' 6+'(:' '(92 9 9)(22 9>!1 ?1 7*&, 2 :&(2) 8(': 96(8+ ) )6(8' #& &2+()' & )2(6)) 9+6(&' & &: 889(2: 2' 6+)(68 '(+' 9 6:(6) 9>!1 ?1 7*&, 2 :2)(6 8('6 96(86 ) )22(:) #& &8:(8: & 29(2:) 6:)(+) & &: 822(9& 2' :'&()' '('& 9 :6(99 9>!1 ?1 7*&, 2 )92(:8 2()6 96(26 ) 298(6& #& &+(2) & 2+()+) :2(8& & &: 82(&) 2' :'8(98 '(): 9 )&(2 9>!1 ?1 7*&, 2 26(+' 2(9 9:(+) ) 8:(' #& &+8(89 & 8)()8) :+6(:' & &: 8)6('' 2' ::(2 '()+ 9 2&()6 9>!1 ?1 7*9, 2 2)(6& )(++ 9+(:& ) 8)(&2 #& 9'9(': & +'(:&) )6'()2 & &: 8:+()2 2' :8(+' '(++ 9 28(9) 9>!1 ?1 7*9, 2 8&9(&2 2('6 6(6) ) +&&(): #& 9'8(88 & +:(99) 2'&(': & &: 8:9(2& 2' :&9(:: '(9+ 9 8:(8+ 9>!1 ?1 7*9, 2 886(8: )(+2 69(82 ) +89(22 #& 96(8: & ++(88) 2)9(2 & &: 862()9 2' :&2(+6 '(6+ 9 +9(96 9>!1 ?1 7*9, 2 +6)(6 )(2& 62()6 2 '66(+' #& 9&'(+ & &'6(') 8&6(9' & &: 86(6) 2' :9(+' '(86 9 &''(:2 9>!1 ?1 7*9, 8 ''8(& 2()' 69(+& 2 ')(& #& 9&2(&2 & &'8(9)) 88:() & &: 896(+8 2' :9)('2 () 9 &'8() 9>!1 ?1 7*9, 8 ')+(+2 8(2 98(69 2 )2(9+ #& 999(8: & &9()2) +6)(2+ & &: 8&8(&) 2' :6(& (:9 9 &)(:+ 9>!1 ?1 7*9, 8 9(:2 8(98 98(&+ 2 &&8(9: #& 96'(68 & &+(:)2 ''2(2: & &: 8&(62 2' :6)(+ '(96 9 &&:(6: 9>!1 ?1 7*9, 8 +9(++ 8(:6 6'(8: 2 &+'('+ #& 962(62 & &&:(:&2 ')+(6+ & &: 86(99 2' ::&()2 '()) 9 &96() 9>!1 ?1 7*9, () *) +, ) -. ) ) !) !/) 0",)!"" #$%&&'()'*)+, ) /)-./01 - 0 ) #$%&&'()'*)+, 1" ) / 0 7 9 < 789 = 789 435+! 7 9 415+ 7 9 -. 7 9 -. 7 9 0 1" 79 0 3 79 . 79 785>9 -1* 8 &:)(99 +(28 9:(82 2 9:()6 #& 9:6(8) & &9&(92 9('6 & &: 8')(2) 2' ::+('8 &(9) 9 &66(:& 9>!1 ?1 7*9, 8 92(29 '(' 9&(2 2 6&(& #& 9)&(&& & &9+()82 +(:& & &: 2++(+ 2' :))(69 '(+) 9 &::(') 9>!1 ?1 7*9, 8 92+()) '( 9(+9 2 629(' #& 9)+(:' & &62()82 &:&(:' & &: 2+(2' 2' :26(&9 '(&2 9 &):(8) 9>!1 ?1 7*9, 8 66(66 +(:' 99(+2 2 :99(+8 #& 92)()2 & &::(982 99(98 & &: 286(99 2' :8(29 (6 9 &2)(9) 9>!1 ?1 7*9, 8 :':(&: '(+8 99(+ 2 :+)(22 #& 986(68 & &)9()'2 92)(2 & &: 22)(&+ 2' :8+(26 &(99 9 &82(2' 9>!1 ?1 7*9, 8 :):(8: &(:' 9()2 2 ):)(' #& 9+&(2+ & &2&(22 69:(:' & &: 2)2(29 2' :+8()& &(:) 9 9''('' 9>!1 ?1 7*9, 8 )&8() &(:+ 9&(): 2 22(9) #& 6'(+6 & &8&(82 6+)(2) & &: 2:8(9 2' )'8(62 '(92 9 99()' 9>!1 ?1 7*9, 8 )+('9 &(82 9&(89 2 228(&: #& 6(&8 & &+&(+2 ::2(): & &: 268(2 2' )8(9 '(6: 9 9&2(99 9>!1 ?1 7*9, 8 2:9()' &()9 &8()+ 2 89+(&8 #& 6&'(&+ & 9'9(9)2 )8()8 & &: 29+(6 2' )&8(: (: 9 96('2 9>!1 ?1 7*9, 8 8)(86 &(&9 &:('+ 2 +'('9 #& 6&8(6) & 96(&62 )8'(69 & &: 29'(+: 2' )9+(2 (98 9 9:6(: 9>!1 ?1 7*9, 8 822(2: ()8 &)(86 2 +)'()& #& 69:(82 & 9&6(6:2 26'('& & &: 2&9(&2 2' )6+(2 ('8 9 9))(+9 9>!1 ?1 7*9, 8 +9+(9' (&2 &8(8) 8 '&'(+6 #& 669(98 & 996(&2 8''(96 & &: 2:(:' 2' ):8()6 '(+9 9 92+(': 9>!1 ?1 7*9, 8 +++(&) '(9 9'(96 8 '2+(86 #& 6:'(:9 & 96&(282 8:+(&6 & &: 2'8(& 2' ))2('+ ()2 9 9+'(&' 9>!1 ?1 7*9, + ')6(&8 +()8 9(8: 8 69(88 #& 6:2(+6 & 9:(&82 +&9(&8 & &: 2''(62 2' )2:(9+ (': 9 6'(66 9>!1 ?1 7*9, + &2(& +( 9(89 8 &':(82 #& 6)6(28 & 9:8(+92 +8:(&2 & &: )+9(69 2' )8&(8: '(+ 9 6()2 9>!1 ?1 7*9, + 8+(+ 8(+: 9'(:) 8 &)2(88 #& 62(&2 & 9))(968 '62(&8 & &: )8)(26 2' )+'('8 '(6 9 6&(6+ 9>!1 ?1 7*9, + &:(: +(:' 9(&6 8 9&8()+ #& 622(26 & 929(8'8 '8('+ & &: )8'('2 2' )+2(92 '(+ 9 69(99 9>!1 ?1 7*9, + 9&(+) +(8: 9'(++ 8 98+(&) #& 686(:9 & 98(:88 )8()) & &: )29('2 2' 2'6(+) '(:2 9 66()& 9>!1 ?1 7*9, + 92:(': '(: 9'(+2 8 6:'(6 #& 6+()' & 98+(2&8 &&+(8 & &: )):(28 2' 2&(+' '(68 9 6:&(9) 9>!1 ?1 7*9, + 69)() '(&2 9'(2 8 :'(:: #& 6+8()+ & 9+2(+&8 &8+(+: & &: ):8(68 2' 2&'(+' '(& 9 6)9(6 9>!1 ?1 7*9, + 6+8(& '(9+ 9('9 8 :2(: #& :':(+) & 6')(9&8 9:'(+ & &: ):'(+8 2' 2&+(' '(& 9 626(& 9>!1 ?1 7*9, + ::+()2 '(8 9(') 8 )9&(' #& :9(9+ & 66(8)8 6(6 & &: )69(9& 2' 292(66 '()8 9 68:(6+ 9>!1 ?1 7*9, + )&(:' '(29 9'(9 8 )+&(2: #& :&'(+ & 6&9()98 62&(: & &: )9:(:) 2' 26)('' '(9 9 6+)(++ 9>!1 ?1 7*9, + )86(&& +(+2 9(+8 8 2:6(6: #& :&8(9' & 69&(98 :99(8: & &: )&2(+6 2' 2:6(9' (9& 9 :'8(& 9>!1 ?1 7*9, + 26:(2: +(89 9&(+) 8 8:(') #& :9:(6: & 69+(+68 :+6(6) & &: )&'(:+ 2' 2)(+ '(9) 9 :8(22 9>!1 ?1 7*9, + 8'8(': +(8' 96()8 8 82)(6: #& :6&(8' & 662()'8 )::(8: & &: )9('9 2' 2)+(92 '(62 9 :&+(98 9>!1 ?1 7*9, + 8)+(&' +(69 9:(2 8 +9)(26 #& ::'('6 & 6:6(8'8 2)(6 & &: )':(:+ 2' 22)(9) '()2 9 :9+()' 9>!1 ?1 7*9, + +9(' +()8 98('9 8 ++2(28 #& ::2(:6 & 6)(8&8 222(8 & &: :+2(+' 2' 289(8 '(26 9 :6+(82 9>!1 ?1 7*9, + ++9('& +(+' 98(+: + ':8(8' #& :):(69 & 6)8(2+8 898(&' & &: :8+(89 2' 28+(+6 '(66 9 :)'(9+ 9>!1 ?1 7*9, ' '::(&& +(+) 9+(& + &'('2 #& :29(:9 & 62:(898 8++(62 & &: :8(:: 2' 2+)(2: '( 9 :2(' 9>!1 ?1 7*9, ' )(2' '(&: 9+(89 + 8'(:+ #& :8(29 & 68&(898 +:+(++ & &: :29() 2' 8'9(:9 '(: 9 :8(8) 9>!1 ?1 7*9, ' 22(2) '(6& 6&(&6 + &6'()) #& :+'(&6 & 68+(2&+ '&'(') & &: :)6(6) 2' 8'(8 '(2) 9 :+&(22 9>!1 ?1 7*9, ' &99(9 '(9) 6(+ + &+:(9' #& :+8(: & 6+:(88+ '26(2' & &: ::)(9+ 2' 8)(& '(: 9 )'&(26 9>!1 ?1 7*9, ' &2('' '(9) 6(+ + 99&(98 #& )'9(68 & :''(')+ (28 & &: ::'(+6 2' 8&'() '('' 9 )'+(68 .F3/3/ C$BC$B B Benjamin Hand Digitally signed by Benjamin Hand Date: 2021.08.30 15:02:26 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2021.08.31 07:22:35 -08'00' TD Shoe Depth: PBTD: Jts. 2 33 Yes X No X Yes No 60 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg)Rate (bpm):Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Casing (Or Liner) Detail Shoe 11 3/4 Rotate Csg Recip Csg Component Size Wt. Setting Depths Ft. Min.PPG9.4 Shoe @ 1500.74 FC @ Top of Liner1,414.97 CASING RECORD County State Alaska Supv.R Pederson / J Richardson Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.Whiskey Gulch 1 Date Run 12-Aug-21 Grade THD Make Length Bottom Top DWC/C Innovex 1.58 1,500.74 1,499.16 Csg Wt. On Hook:73,000 Type Float Collar:Innovex No. Hrs to Run: 100 540FIRST STAGE10.5Tuned Prime 75 Spud Mud 15.8 4 Bump press 5 9.4 5 Floats Held 0 1,500.001,510.00 1,414.00 CEMENTING REPORT Csg Wt. On Slips: 135/136.2 1340 94 Halliburton 58,000 Spud Mud 12 130 Type of Shoe:Innovex Casing Crew:Weatherford Ran 17 centralizers www.wellez.net WellEz Information Management LLC ver_04818br 4 Cement to surface Bump Plug? 14:33 8/12/2021 Casing 10 3/4 45.5 L-80 DWC/C Vam 82.89 1,499.16 1,416.27 Float collar 11 3/4 BTC Innovex 1.30 1,416.27 1,414.97 Casing 10 3/4 45.5 L-80 DWC/C Vam 1,389.51 1,414.97 25.46 Pup 10 3/4 45.5 L-80 DWC/C Vam 2.39 25.46 23.07 Hanger 13 5/8 DWC/C Cactus Type II 360 1.16 4.5 1.18 23.07 21.89 Type II 300 2.4 TD Shoe Depth: PBTD: Jts. 2 159 30 Yes X No X Yes No 4 Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?:Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg)Rate (bpm):Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface?Yes X No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Casing (Or Liner) Detail Float Shoe 8 5/8 Rotate Csg Recip Csg Component Size Wt. Setting Depths Ft. Min.PPG9.5 Shoe @ 7701.67 FC @ Top of Liner7,616.12 CASING RECORD County State Alaska Supv.R Pederson / J Riley Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.Whiskey Gulch 1 Date Run 25-Aug-21 Grade THD Make Length Bottom Top BTC 2.02 7,701.67 7,699.65 Csg Wt. On Hook:Type Float Collar:Innovex No. Hrs to Run: 100 1240FIRST STAGE10.5Tune Primed 40 6% KCL Mud 15.8 30 Bump press 12.5 9.5 5 Floats Held ~1430' 7,701.677,710.00 CEMENTING REPORT Csg Wt. On Slips: 345.5/349.6 1240 0 Halliburton 12 333 Type of Shoe:Innovex Casing Crew:Weatherford www.wellez.net WellEz Information Management LLC ver_04818br 4 CBL Bump Plug? 6:29 8/25/2021 7 5/8'' Casing jts 7 5/8 29.7 L-80 BTC 82.40 7,699.65 7,617.25 Float Collar 8 5/8 BTC 1.13 7,617.25 7,616.12 7 5/8'' Casing Jts 7 5/8 29.7 L-80 USS-CDC 6,387.75 7,616.12 1,228.37 Swell Packer 9 5/8 29.7 L-80 USS-CDC 8.81 1,228.37 1,219.56 7 5/8'' Casing Jts 7 5/8 29.7 L-80 USS-CDC 1,196.89 1,219.59 22.70 7 5/8'' Casing Pup Jt 7 5/8 29.7 L-80 USS-CDC 2.42 22.70 20.28 Hanger 10 3/4 USS-CDC 0.45 20.28 19.83 I II 800 2.4 I II 145 1.24 6 6% KCL Mud T65 Testing 12-22-2021 •5098 TVDss (6141’ MD)•Res P @ 0.45 gradient = 2294 psi•Perf BHP calc = 1215 psi (1079 psi drawdown)•No gas to surfacePerf 12:10 pm 12/22/2021WHP = 1016 psi no pressure changes47% drawdownNo flarable gas, minor LELsChoke cracked to vent (12 hrs to go from 1016psi to 22 psi)6142-6155’ MD Perf 11:25 am 12/28/2021WHP = 1024 psi (30% Under Balance)5 min = 1028 psi10 min = 1028 psi15 min = 1029 psiWHP = 1031 psi ~1.5 hrs laterFirst gas at WHP = 220 psi650 mscfdFlowed for ~1.5 hrsOvernight build of ~20psi•3748 TVDss (4498’ MD)•Res P @ 0.45 gradient = 1687 psi•Perf BHP calc = 1171 psi (507 psi drawdown)•First gas BHP calc = 220 psi (1447 psi drawdown)•8:20am dec 29•21 hrs later fluid level at 4350’MD•Plug at 4790’ MD•20 bbl of water in the wellDrop pressure by 930psi in ~1.5 hrsT48 Testing – 12-28-20214498-4518’ MD Perf 12:10 pm 12/29/2021WHP = 1007 psi (32% Under Balance)5 min = 1005 psi10 min = 1003 psi15 min = 1002 psiWHP = 1002 psi ~30 min laterFirst gas at WHP = 38 psi690 mscfdFlowed for ~20minT48 Testing – 12-29-2021•3748 TVDss (4498’ MD)•Res P @ 0.45 gradient = 1687 psi•Perf BHP calc = 1152 psi (535 psi drawdown)•First gas WHP @ 38 psi, started with a column of fluid•4:30 pm Dec 29 GPT•Fluid level at 4250’MD4498-4518’ MD Perf 11:35 am 1/4/2022WHP = 759 psi (30% Under Balance)5 min = 762psi10 min = 762psiWHP = 764 psi 1 hr laterFirst gas at WHP = 150 psi1.5mmFlowed for ~30 minOvernight build of 45 psi•2822 TVDss (3372’ MD)•Res P @ 0.45 gradient = 1270 psi•Perf BHP calc = 848 psi (422 psi drawdown)•First gas BHP calc = 162 psi (1108 psi drawdown)•Jan 5thfluid level at 2950’ MD•Plug at 3630’MD•31 bbls of water•Fluid level climbing (@2875’ MD) +~4bbls 3.5hrs after prior GPTT18 Testing – 1-4-20223372-3381’ MD •2822 TVDss (3372’ MD)•Res P @ 0.45 gradient = 1270 psi•Fluid level 1/10/2022 ~6 days later = 925 TVDss (1150’ MD)•Calc BHP = 1066 psi•WHP = 208psi•Gas gradient = 0.00531 psi/ft x 925’ TVDss = 5psi•Water gradient = 0.45 psi/ft x 1897’ TVDss = 854psi •204 psi underbalancedT18 Testing – 1-10-20223372-3381’ MD •2660’ TVDss•Res P @ 0.45 gradient = 1197 psi•Fluid level at 1490’ MD after overnight build•Gas flowed at 200 psi WGPT14 Testing – 2-16-20222890-2910’ MDPerf 4:40 pm 2/16/2022WHP = 884 psi (20% Under Balance)5 min = 884psi10 min = 884 psi15 min = 884 psiRes gas at 200 psiPost flow fluid level at 1490’ MDShut in well over night, not measuring tubing pressure until opened back up in the AM at 508 psiEnd of T14 test •1976 TVDss•Res P @ 0.45 gradient = 889 psiT10 Testing – 2-17-20222064-2078’ MD T10 Testing – 2-17-2022 to 2-21-2022tubingTotal production from T-10 = 15 MMSCF Whiskey Gulch 1 Core Summary 2. Facility NameWhiskey GulchPercent100.00%Official Use Authorization SafetyMCFLease UseMCFConservatiMCFWasteMCFReviewed by:COMMISSIONERComm.Comm.19. Remarks:Authorized Name and Digital Signature with date:Heather ChapaSTATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONFACILITY REPORT OF PRODUCED GAS DISPOSITION1. Facility Number 3. Field 4. Operator 5. Month/Year of Disposition231000006 Whiskey Gulch Hilcorp Alaska.LLC Mar 22Disposition Volume MCF20. For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold0 Pool Name Pool Code7. Reinjected0 Whiskey Gulch 9405008. Flared or vented 1 hour or less0 9. Flared or vented more than 1 hour (see instr.)0 10. Pilot and Purge0 11. Assist Gas0 13. Other (see instructions)0 14. TOTAL VOLUME (ITEMS 6-13)0 12. Fuel gas used in lease operations.0 15. NGL Gas Equivalent0 16. Purchased gas0 17. Transferred from:0 18. Transferred to: (Express as a negative #)0 I hereby certify that the foregoing is true and correct to the best of my knowledge.Revision? Date of Revision:Title: Production AnalystContact Phone: 713-209-2469Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235.Contact Email:heather.chapa@hilcorp.comForm 10-422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.govDigitally signed by Heather ChapaDN: cn=Heather Chapa, c=US,email=heather.chapa@hilcorp.comDate: 2022.04.21 15:23:11 -05'00'HeatherChapa 10. GAS(BBL)11. OIL(BBL)12. WATER(BBL)13. GAS(BBL)Whiskey Gulch 01 294050080000Title:Heather Chapa 4/21/2022heather.chapa@hilcorp.comForm 10-405 Rev. 10/2021 20 AAC 25.235I hereby certify that the foregoing is true and correct to the best of my knowledge.14.TOTAL 0Production AnalystRevision? Date of Revision:Authorized Name and Digital Signature with date:Contact Phone:50-231-20079-00-0000713-209-2469Contact Email::6. Days in Oper.STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONMONTHLY PRODUCTION REPORT20 AAC 25.230Name of Operator: HILCORP ALASKA, LLC0Mar-221. Well No. 2. API No.50-XXX-XXXXX-XX-XX3. Type(see instruct.)4. Field & Pool Code5. Method(see instruct.)7. Avg. FTP psig (see instruct.)DAILY AVG. PRODUCTION9. WATER(BBL)TOTAL MONTHLY PRODUCTION8. OIL(BBL)Submit in PDF format to aogcc.reporting@alaska.gov0000Month and Year:Digitally signed by Heather ChapaDN: cn=Heather Chapa, c=US,email=heather.chapa@hilcorp.comDate: 2022.04.21 15:23:23 -05'00'HeatherChapa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ĐĂƐŝŶŐ͘ŝƌĐƵůĂƚĞĚнͬͲϭϬďďůƐŽĨϲй<>͘&ƌĞĞǌĞƉƌŽƚĞĐƚƐƵƌĨĂĐĞƉŝƉĞǁŝƚŚϲϬͬϰϬDĞƚŚĂŶŽů͘ZŝŐĚŽǁŶŚŽƚŽŝůƚƌƵĐŬ͘/ ŐĂƵŐĞƐŚŽǁŝŶŐϬƉƐŝ͘ ϭϮͬϬϳͬϮϬϮϭͲdƵĞƐĚĂǇ ϭϮͬϬϲͬϮϬϮϭͲDŽŶĚĂǇ ϭϭͬϬϵͬϮϬϮϭͲdƵĞƐĚĂǇ &ůƵŝĚWĂĐŬtŚŝƐŬĞǇ'ƵůĐŚϬϭ͘ WƵŵƉϭďďůEĞĂƚDĞƚŚŝŶƚŽϭϬͲϯͬϰyϳͲϱͬϴĂƐŝŶŐ͘ƵŵƉĞĚƵƉĨƌŽŵϮϬϬϬƚŽϯϬϬϬƉƐŝϳƚŝŵĞƐ͕ďƵƚƐƚŝůůŶĞǀĞƌƐƚĂďŝůŝǌĞĚ͘ &ŝŶĂůǁĂƐϰϬϬƉƐŝůŽƐƐŝŶϭϬŵŝŶƵƚĞƐ;&/>Ϳ͘ >ĞĨƚǁĞůůǁŝƚŚϬͬϬͬϬƉƌĞƐƐƵƌĞƐ͘ ϭϭͬϭϬͬϮϬϮϭͲtĞĚŶĞƐĚĂǇ ƚƚĞŵƉƚƚŽŐĞƚD/dƚĞƐƚŽĨϳͲϱͬϴΗǆϭϬͲϯͬϰΗĂŶŶƵůƵƐǁŝƚŚŶĞĂƚŵĞƚŚŽŶt'ͲϬϭƚŽϮϱϬϬƉƐŝ͘ hŶĂďůĞƚŽŐĞƚƉĂƐƐŝŶŐƚĞƐƚ͘ůĞĚŽĨĨхϱϬϬƉƐŝŝŶĨŝŶĂůϯϬŵŝŶƵƚĞƐ͘ &ůƵŝĚƉĂĐŬƚƵďŝŶŐǁŝƚŚŝĞƐĞů͘ >ĞĨƚǁĞůůǁŝƚŚϬͬϬͬϬƉƌĞƐƐƵƌĞƐ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭϮͬϭϰͬϮϬϮϭͲdƵĞƐĚĂǇ &ŽǆŶĞƌŐǇĐƌĞǁĂƌƌŝǀĞƐĂƚĨĂĐŝůŝƚǇĂŶĚŽďƚĂŝŶƐƉĞƌŵŝƚ͕d'^D͘&ŝƌĞƵƉĐŽŝůĂŶĚEϮƉƵŵƉŝŶŐƐƉƌĞĂĚ͘DĂŬĞƵƉ, ŝŶĐůƵĚŝŶŐϮͲϭͬϴΗƐƚŝŶŐĞƌĂŶĚϮͲϭͬϴΗďŝŐŚŽůĞĐĞŵĞŶƚŝŶŐŶŽǌǌůĞ͘^ƚĂďŽŶƚŽǁĞůůĂŶĚƉƌĞƐƐƵƌĞƚĞƐƚƚŽϮϱϬƉƐŝůŽǁͬϯϱϬϬƉƐŝ ŚŝŐŚ͘KƉĞŶǁĞůůĂŶĚZ/,ƚŽϭϬϬϬΖǁŚŝůĞĐŽŽůŝŶŐĚŽǁŶEϮƉƵŵƉ͘ŽŵĞŽŶůŝŶĞǁŝƚŚEϮĚŽǁŶdǆd'ďĂĐŬƐŝĚĞĂƚϱϬϬ ƐĐĨͬŵŝŶ͕ƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞƐƚĂďŝůŝǌĞƐĂƚϭϱϬϬƉƐŝ͘ĨƚĞƌϮϱ͕ϬϬϬƐĐĨƉƵŵƉĞĚďĞŐŝŶƚŽŐĞƚƌĞƚƵƌŶƐƚŚƌŽƵŐŚdƚŽƚĂŶŬ͘Z/, ƌĞŐƵůĂƚŝŶŐƐƉĞĞĚƚŽŵĂŝŶƚĂŝŶĂƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞŽĨϭϱϬϬƉƐŝΛϱϬϬƐĐĨͬŵŝŶ͘ĨƚĞƌϭϬϬďďůƐŽĨƌĞƚƵƌŶƐƚĂŬĞŶŝŶĐƌĞĂƐĞƌĂƚĞ ƚŽϭϱϬϬƐĐĨͬŵŝŶƚŽĞƐƚĂďůŝƐŚƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞŽĨϮϬϬϬƉƐŝ͘ŽŶƚŝŶƵĞƚŽZ/,ĂŶĚƉĂƌŬĂƚϳϰϬϬΖ͘ĨƚĞƌϯϮϬ͕ϬϬϬƐĐĨŽĨEϮŝƐ ƉƵŵƉĞĚĂŶĚϮϱϬďďůƐŽĨƌĞƚƵƌŶƐƚĂŬĞŶWKK,ĂŶĚƉĂƌŬĂƚϲϴϬϬΖĚƵĞƚŽǀŽůƵŵĞŽĨEϮƌĞŵĂŝŶŝŶŐ͘ϰϬϬ͕ϬϬϬƐĐĨŽĨEϮ ƉƵŵƉĞĚĂŶĚΕϯϮϬďďůƐŽĨĨůƵŝĚƌĞƚƵƌŶƐƚĂŬĞŶ͘WKK,͘&ŝŶĂůƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞŽĨϮϴϱϬƉƐŝǁĂƐƚƌĂƉƉĞĚŽŶǁĞůů͘ZDK͘ ϭϮͬϭϱͬϮϭͲtĞĚŶĞƐĚĂǇ WĞƌĨŽƌŵĞĚD/d/;ϳͲϱͬϴΖǆϭϬͲϯͬϰΖͿ͘ŝĚŶŽƚƉĂƐƐ͘ůĞĚ/ƚŽǌĞƌŽƉƐŝĂĨƚĞƌĨĂŝůŝŶŐD/dĂŶĚŝƚďƵŝůƚďĂĐŬƚŽϰϴϬƉƐŝ͘ZDK /ŶŝƚŝĂůƉƌĞƐƐƵƌĞƐ͗ dďŐͲϮϰϮϬƉƐŝ /ͲϭϮϬƉƐŝ KͲϬƉƐŝ ϭϮͬϭϲͬϮϭͲdŚƵƌƐĚĂǇ ϭϮͬϭϯͬϮϬϮϭͲDŽŶĚĂǇ &ŽǆŶĞƌŐǇĐƌĞǁĂƌƌŝǀĞƐĂƚĨĂĐŝůŝƚǇĂŶĚŽďƚĂŝŶƐƉĞƌŵŝƚ͕d'^D͘tĂƌŵƵƉdĞƋƵŝƉŵĞŶƚĂŶĚĐƌĂŶĞ͘^ƉŽƚŚĞĂƚĞƌ͕ůŝŐŚƚƉůĂŶƚ ĂŶĚŵĂŶůŝĨƚ͘ƌĞĂŬŽĨĨƚƌĞĞĐĂƉĂŶĚĨůĂŶŐĞƵƉĂĚĂƉƚĞƌƐƉŽŽů͘EhKWƚŽƚƌĞĞĂŶĚƐƚĂƌƚKWdĞƐƚĂŐĂŝŶƐƚƐǁĂď͘K' ǁĂŝǀĞĚǁŝƚŶĞƐƐďǇ:ŝŵZĞŐŐŽŶϭϮͬϭϭͬϮϭĂƚϭϱ͗ϱϯ͘&ƵŶĐƚŝŽŶƚĞƐƚƵƉƉĞƌ;ďůŝŶĚͬƐŚĞĂƌͿĂŶĚůŽǁĞƌ;ƉŝƉĞͬƐůŝƉͿƌĂŵƐ͘WƌĞƐƐƵƌĞ ƚĞƐƚƵƉƉĞƌƌĂŵƐ͕ůŽǁĞƌƌĂŵƐ͕ĨůŽǁĐƌŽƐƐǀĂůǀĞƐ͕ĐŚŽŬĞŵĂŶŝĨŽůĚǀĂůǀĞƐĂŶĚŝŶŶĞƌƌĞĞůǀĂůǀĞƚŽϮϱϬƉƐŝůŽǁͬϯϱϬϬƉƐŝ ŚŝŐŚ͘ůůƚĞƐƚƐƉĂƐƐĞĚ͘^ĞĐƵƌĞůŽĐĂƚŝŽŶĂŶĚ^&E͘ d'W^/ϮϰϮϬ /ͬW^/ϯϲϬ ϭϮͬϭϳͬϮϭͲ&ƌŝĚĂǇ d'W^/ϮϰϮϬ /ͬW^/ϯϭϬ ϭϮͬϭϴͬϮϭͲ^ĂƚƵƌĚĂǇ d'W^/ϮϰϮϬ /ͬW^/ϮϵϬ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭϮͬϭϵͬϮϭͲ^ƵŶĚĂǇ d'ϮϰϮϬW^/ /ϮϲϬW^/ ϭϮͬϮϬͬϮϭͲDŽŶĚĂǇ d'ϮϰϮϬ /ϭϵϬ;ĂĚĚĞĚŶĞǁƚƵďŝŶŐĂŶĚŐĂƵŐĞĂďŽǀĞŐƌĂĚŝŶŐͿ ŵďŝĞŶƚƚĞŵƉϮϲ& ϭϮͬϮϭͬϮϭͲdƵĞƐĚĂǇ zĞůůŽǁ:ĂĐŬĞƚͲůŝŶĞĂƌƌŝǀĞŽŶůŽĐĂƚŝŽŶ͘ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘D/Zh͕͘Dh'WdĂŶĚϮͲϳͬϴΗΗǆϭϮΖƉĞƌĨŽƌĂƚŝŶŐŐƵŶ͘ 'Zͬ>ƚŽƚŽƉƐŚŽƚсϭϱ͘ϱΖ͘ůĞĞĚt,WĚŽǁŶƚŽϭϴϳϬƉƐŝ͕͘WdůƵďƌŝĐĂƚŽƌ͘,ĂǀĞůĞĂŬĂƚĐŽŶŶĞĐƚŝŽŶĂďŽǀĞǁŝƌĞůŝŶĞǀĂůǀĞ͘ ŚĂŶŐĞŽƵƚŽͲƌŝŶŐ͕^ƚŝůůŚĂǀĞůĞĂŬ͘ŚĂŶŐĞŽƵƚůƵďƌŝĐĂƚŽƌƐĞĐƚŝŽŶĂďŽǀĞǁŝƌĞůŝŶĞǀĂůǀĞĂŶĚŽͲƌŝŶŐƐ͘^ƚŝůůŚĂǀĞůĞĂŬ͘Z ůƵďƌŝĐĂƚŽƌĂŶĚǁŝƌĞůŝŶĞǀĂůǀĞ͘ƌŝŶŐďĂĐŬƚŽƐŚŽƉŝŶ<ĞŶĂŝƚŽƚƌŽƵďůĞƐŚŽŽƚĂŶĚͬŽƌĐŚĂŶŐĞŽƵƚǁŝƌĞůŝŶĞǀĂůǀĞ͘^&'͕d' ϭϴϵϮW^/ůĞĞĚƉƌĞƉĞƌĨŽƌĂƚŝŶŐ/ͬϭϮϬW^/ dDWϭϯ& ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭϮͬϮϮͬϮϭͲtĞĚŶĞƐĚĂǇ zĞůůŽǁ:ĂĐŬĞƚͲůŝŶĞĂƌƌŝǀĞŽŶůŽĐĂƚŝŽŶ͘ ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘Dh'WdĂŶĚϮͲϳͬϴΗǆϭϮΖƉĞƌĨŐƵŶ͘ϲϬĚĞŐƌĞĞƉŚĂƐŝŶŐ͕ϲƐƉĨ WdůƵďƌŝĐĂƚŽƌͬǁŝƌĞůŝŶĞǀĂůǀĞƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ͘Z/,ĂŶĚĨŝŶĚĨůƵŝĚůĞǀĞůĂƚϲϲϬϰΖ͘dĂŐWdĂƚϳϰϬϭΖ͘d'ϭϴϴϴ W^/͕/ϭϬϬW^/͕dDWϮϯ&͘ ^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'K͘KŶĚĞƉƚŚ͘ůĞĞĚt,WĚŽǁŶƚŽϭϴϱϱƉƐŝ͖͘WĞƌĨŽƌĂƚĞϲϭϰϯͲϲϭϱϱΖ;dϲϱͿ /ŶŝƚŝĂůƚƵďŝŶŐсϭϴϱϱƉƐŝ͕,WсϮϮϲϲƉƐŝ͕ϱŵŝŶƚƵďŝŶŐсϭϴϱϱƉƐŝ͕,WсϮϮϲϲƉƐŝ͕ϭϬŵŝŶƚƵďŝŶŐсϭϴϱϱƉƐŝ͕,WсϮϮϲϲ ƉƐŝ͘WKK,͘ůůƐŚŽƚƐĨŝƌĞĚ͘ƵůůƉůƵŐŝƐĚƌǇ͘ ,ĂŶĚŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶƚŽĂƚƚĞŵƉƚƚŽĨůŽǁ͘ƚƚĞŵƉƚƚŽĨůŽǁĂŶĚƚĞƐƚdϲϱǌŽŶĞ͘KƉĞŶĐŚŽŬĞĂŶĚƐƚĞƉĚŽǁŶƉƌĞƐƐƵƌĞƚŽ ϭϬϭϬƉƐŝ͘KŶůǇEϮĂƚƐƵƌĨĂĐĞ͕ŶŽŐĂƐ͘^ŚƵƚŝŶǁĞůůĂŶĚƉƌĞƉƚŽƌƵŶ'Wd͘DhĂŶĚZ/,ǁŝƚŚ'Wd͘ /ŶŝƚŝĂůdƵďŝŶŐƉƌĞƐƐƵƌĞсϭϬϭϬƉƐŝ͘&ůƵŝĚůĞǀĞůсϲϲϯϬΖ͘ WƵůůƵƉŚŽůĞƚŽƉĞƌĨŝŶƚĞƌǀĂů͘,WсϭϮϮϵƉƐŝ͕,dсϵϵĚĞŐ&͘dƵďŝŶŐƉƌĞƐƐсϭϬϭϰƉƐŝ͘ŽǁŶůŽĂĚϮϬΖŐƵŶƚŽϭϮΖŐƵŶ͘Dh ĂŶĚZ/,ǁŝƚŚ'WdĂŶĚϮͲϳͬϴΗǆϮϬΖ;ϭϮΖůŽĂĚĞĚͿƉĞƌĨŐƵŶ͘^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'K͕ĐŽŶĨŝƌŵŽŶĚĞƉƚŚ͘ZĞͲƉĞƌĨ ϲϭϰϯͲϲϭϱϱΖ͘EŽŚĂŶŐĞŝŶƐƵƌĨĂĐĞŽƌĚŽǁŶŚŽůĞƉƌĞƐƐƵƌĞ͘/ŶŝƚŝĂůƚƵďŝŶŐƉƌĞƐƐƵƌĞсϭϬϭϱƉƐŝ͕,WсϭϮϰϵƉƐŝ͘ϱŵŝŶ ƉƌĞƐƐƵƌĞсϭϬϭϱƉƐŝ͕,WсϭϮϰϵƉƐŝ͘ϭϬŵŝŶƉƌĞƐƐƵƌĞсϭϬϭϱƉƐŝ͘,WсϭϮϰϵƉƐŝ͘WKK,͘'ƵŶĂƚƐƵƌĨĂĐĞ͘ůůƐŚŽƚƐĨŝƌĞĚ͘ ƵůůƉůƵŐĚƌǇ͘ >ĂǇĚŽǁŶůƵďƌŝĐĂƚŽƌĂŶĚǁŝƌĞůŝŶĞǀĂůǀĞ͘/ŶƐƚĂůůƚƌĞĞĐĂƉ͘,ĂŶĚŽǀĞƌƚŽŽƉĞƌĂƚŝŽŶƐ͘^&E͘KƉĞŶǁĞůůƚŽǀĞŶƚĂƐŝŶƐƚƌƵĐƚĞĚ͘ dĂŬŝŶŐƉƌĞƐƐƵƌĞĂŶĚŐĂƐƌĞĂĚŝŶŐƐĂƚϭϱͲϯϬŵŝŶƵƚĞŝŶƚĞƌǀĂůƐ͘ ϭϮͬϮϯͬϮϭͲdŚƵƌƐĚĂǇ d'ϮϬW^/ /ͬϬW^/ dDWϯϯ& ϭϮͬϮϰͬϮϭͲ&ƌŝĚĂǇ d'W^/ϰϲϱ /ͬW^/Ϭ dDWϭϴĚĞŐ ϭϮͬϮϱͬϮϭͲ^ĂƚƵƌĚĂǇ d'W^/ϱϮϱ ͬ/W^/Ϭ dDWϮϲ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭϮͬϮϲͬϮϭͲ^ƵŶĚĂǇ d&W^/ϲϵϱ ͬ/W^/Ϭ dDWϰϲ ϭϮͬϮϳͬϮϭͲDŽŶĚĂǇ zĞůůŽǁ:ĂĐŬĞƚ>ĂƌƌŝǀĞŽŶůŽĐĂƚŝŽŶ͘ ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ Dh'WdƚŽŽůƐƚƌŝŶŐĂŶĚWdůƵďƌŝĐĂƚŽƌ͘ dƵďŝŶŐƉƌĞƐƐƵƌĞсϳϱϬƉƐŝ͘/сϬƉƐŝ͘Z/,ǁŝƚŚ'WdƚŽŽůƐƚƌŝŶŐ͘ &ŝŶĚĨůƵŝĚůĞǀĞůĂƚϰϮϬϰΖ͘ ,WĂƚƉĞƌĨŝŶƚĞƌǀĂů;ϲϭϱϬΖͿсϭϱϮϰƉƐŝ͘ WKK,͘DhϯͲϯͬϴΗǆϮϰΖWĞƌĨ'ƵŶ;ůŽǁƐǁĞůůĐŚĂƌŐĞƐͿ͘ WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ͘ ^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'K͘ŽŶĨŝƌŵŽŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞϲϭϯϳͲϲϭϲϭΖ;dϲϱͿǁŝƚŚϯͲϯͬϴΗǆϮϰΖƉĞƌĨŐƵŶ͘ /ŶƚŝĂů͕ϱ͕ϭϬ͕ΘϭϱŵŝŶƵƚĞƚƵďŝŶŐƉƌĞƐƐƵƌĞƐĂůůƚŚĞƐĂŵĞĂƚϳϲϮƉƐŝ͘WKK,͘ ŽŶĨŝƌŵĂůůƐŚŽƚƐĨŝƌĞĚ͘'ƵŶŝƐǁĞƚ͘DhĂŶĚZ/,ǁŝƚŚ'WdĂŶĚƐĂŵƉůĞďĂŝůĞƌ͘ &ůƵŝĚůĞǀĞůсϰϭϱϬΖ͘,WсϭϱϯϮƉƐŝĂƚŵŝĚƉĞƌĨ͘ŽŽůĚŽǁŶEϮƵŶŝƚ͘ WƵŵƉŶŝƚƌŽŐĞŶĚŽǁŶƚƵďŝŶŐ͘&ůƵŝĚƐƚĂƌƚŝŶŐƚŽŵŽǀĞĚŽǁŶŚŽůĞĂƚϭϴϬϬƉƐŝ͘ &ůƵŝĚůĞǀĞůĂƚϰϴϬϬΖ͘^ŚƵƚĚŽǁŶEϮƵŶŝƚĂŶĚƚƌĂƉϮϭϱϬƉƐŝŽŶƚƵďŝŶŐ͘ WKK,͘KďƚĂŝŶĨůƵŝĚƐĂŵƉůĞĨƌŽŵďĂŝůĞƌĂƚƐƵƌĨĂĐĞ͘ >ĂǇĚŽǁŶůƵďƌŝĐĂƚŽƌͬǁŝƌĞůŝŶĞǀĂůǀĞĂŶĚEhϳΗƌŝƐĞƌĂďŽǀĞƐǁĂďǀĂůǀĞ͘ ^&E d'ϮϭϱϬ /ͬϮϲϬ dDWϯϴ& ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭϮͬϮϴͬϮϭͲdƵĞƐĚĂǇ zĞůůŽǁ:ĂĐŬĞƚͲůŝŶĞĐŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ DhϳͲϱͬϴΗĐŽŵƉŽƐŝƚĞďƌŝĚŐĞƉůƵŐ͘ WdƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ͘ dƵďŝŶŐƉƌĞƐƐƵƌĞсϭϴϬϬƉƐŝ͘ /ͬϭϮϱƉƐŝ dDWϯϳ&͘Z/,ǁŝƚŚƉůƵŐ͘^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'K͘KŶĚĞƉƚŚ͘ ^ĞƚƉůƵŐĂƚϰϳϵϬΖƚŽŝƐŽůĂƚĞdϲϱ͘ dĂŐƉůƵŐƚŽĐŽŶĨŝƌŵƐĞƚ͘ WKK,͘ ůĞĞĚƉƌĞƐƐƵƌĞĚŽǁŶĨƌŽŵϭϳϳϬƉƐŝƚŽϭϬϮϰƉƐŝ͘Z/,ǁŝƚŚϯͲϯͬϴΗǆϮϬΖŐƵŶ͘^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'K͘KŶĚĞƉƚŚ͘ WĞƌĨŽƌĂƚĞdϰϴĨƌŽŵϰϰϵϴͲϰϱϭϴΖ͘ /ŶŝƚŝĂůƉƌĞƐƐƵƌĞсϭϬϮϰƉƐŝ͘ ϱŵŝŶƉƌĞƐƐƵƌĞсϭϬϮϴƉƐŝ ϭϬŵŝŶƉƌĞƐƐƵƌĞсϭϬϮϴƉƐŝ͘ ϭϱŵŝŶƉƌĞƐƐƵƌĞсϭϬϮϵƉƐŝ͘'ƵŶĂƚƐƵƌĨĂĐĞ͘ŽŶĨŝƌŵĂůůƐŚŽƚƐĨŝƌĞĚ͘'ƵŶŝƐƌǇ͘ Z/,ǁŝƚŚ'Wd͘ ,WĂƚŵŝĚƉĞƌĨ;ϰϱϬϴΖͿсϭϭϯϳƉƐŝ dĂŐƉůƵŐ͕ŶŽĨůƵŝĚŝŶǁĞůů͘ WKK,͘>ĂǇĚŽǁŶůƵďƌŝĐĂƚŽƌ͘/ŶƐƚĂůůŶŝŐŚƚĐĂƉ͘ ,ĂŶĚŽǀĞƌǁĞůůƚŽƉƌŽĚƵĐƚŝŽŶƚŽƚĞƐƚǌŽŶĞ͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭϮͬϯϭͬϮϭͲ&ƌŝĚĂǇ d'W^/ϳϬϬ ͬ/W^/ϮϬ dDWϮϰ ϭϮͬϮϵͬϮϭͲtĞĚŶĞƐĚĂǇ zĞůůŽǁ:ĂĐŬĞƚͲůŝŶĞĐŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ dƵďŝŶŐƉƌĞƐƐƵƌĞсϮϬƉƐŝ͘ ĂůůŽƵƚĨŽƌEϮ͘ Dh'Wd͘ /ͬϬƉƐŝ dDWϯϳ&͖Z/,ǁŝƚŚ'WdĂŶĚƐĂŵƉůĞďĂŝůĞƌ͘&ŝŶĚ&ůƵŝĚ>ĞǀĞůсϰϯϱϬΖ͘ KďƚĂŝŶĨůƵŝĚƐĂŵƉůĞ͘ WKK,͖͘ŽŽůĚŽǁŶEϮƵŶŝƚĂŶĚZhŚĂƌĚůŝŶĞ͘ DhϮͲϳͬϴΗǆϮϬΖƉĞƌĨŐƵŶ͘ WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ͘ Z/,ǁŝƚŚƉĞƌĨŐƵŶĂŶĚƉƵŵƉEϮƚŽƉƌĞƐƐƵƌĞƵƉǁĞůůƚŽϭϬϬϬƉƐŝ͘ ^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'KĂŶĚĐŽŶĨŝƌŵŽŶĚĞƉƚŚ͖͘WĞƌĨŽƌĂƚĞdϰϴǌŽŶĞĨƌŽŵϰϱϰϰͲϰϱϲϰΖ͘ /ŶŝƚŝĂůƉƌĞƐƐƵƌĞсϭϬϬϳƉƐŝ ϱŵŝŶƉƌĞƐƐсϭϬϬϱƉƐŝ ϭϬŵŝŶƉƌĞƐƐсϭϬϬϯƉƐŝ ϭϱŵŝŶƉƌĞƐƐсϭϬϬϮƉƐŝ WKK,͘ůůƐŚŽƚƐĨŝƌĞĚ͘'ƵŶŝƐǁĞƚ͖͘,ĂŶĚŽǀĞƌǁĞůůƚŽƉƌŽĚƵĐƚŝŽŶƚŽƚĞƐƚdϰϴǌŽŶĞ͖͘Z/,ǁŝƚŚ'WdĂŶĚĨŝŶĚĨůƵŝĚĂƚϰϮϱϬΖ͘ Z/,ǁŝƚŚϳͲϱͬϴΗW͕ƐĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'K͕ĐŽŶĨŝƌŵŽŶĚĞƉƚŚ͘^ĞƚWĂƚϯϲϯϬΖ͘ dĂŐƉůƵŐƚŽĐŽŶĨŝƌŵŝƚΖƐƐĞƚ͘ WKK,͘ WƌĞƐƐƵƌĞǁĞůůƚŽϳϬϬƉƐŝǁŝƚŚEϮ͖͘ZDK ϭϮͬϯϬͬϮϭͲdŚƵƌƐĚĂǇ d'ϳϬϬƉƐŝ /ͬϱϴƉƐŝ dDWϮϬ& ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭͬϭͬϮϮͲ^ĂƚƵƌĚĂǇ d'W^/ϳϬϬ /ͬW^/Ϭ dDWϭϰ ϭͬϮͬϮϮͲ^ƵŶĚĂǇ d'W^/ϳϬϬ /ͬW^/Ϭ dDWϭϮ ϭͬϯͬϮϮͲDŽŶĚĂǇ d'W^/ϳϬϬ /ͬW^/Ϭ dDWϭϮ ϭͬϰͬϮϮͲdƵĞƐĚĂǇ zĞůůŽǁ:ĂĐŬĞƚͲůŝŶĞĂƌƌŝǀĞĂƚůŽĐĂƚŝŽŶ͘ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ ,ĂǀŝŶŐƚƌŽƵďůĞŐĞƚƚŝŶŐƚƌĞĞĐĂƉŽĨĨ͕ŐĞƚŚĞĂƚĞƌƚƌƵŶŬŽŶĐĂƉƚŽƌĞŵŽǀĞ͘ DhϯͲϯͬϴΗǆϴΖƉĞƌĨŐƵŶ͘ WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ͘^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'K͘ŽŶĨŝƌŵŽŶĚĞƉƚŚ͘ WĞƌĨŽƌĂƚĞϯϯϳϯͲϯϯϴϭΖ;dϭϴͿ͘ /ŶŝƚŝĂůƐƵƌĨĂĐĞƉƌĞƐƐсϳϱϵƉƐŝ ϱŵŝŶƉƌĞƐƐсϳϲϮƉƐŝ ϭϬŵŝŶƉƌĞƐƐсϳϲϮƉƐŝ ϭϱŵŝŶƉƌĞƐƐсϳϲϮƉƐŝ͘WKK,ĂŶĚĐŽŶĨŝƌŵĂůůƐŚŽƚƐĨŝƌĞĚ͘ 'ƵŶŝƐĚƌǇ͘,ĂŶĚŽǀĞƌƚŽKƉĞƌĂƚŝŽŶƐƚŽdĞƐƚ͘>ĞĂǀĞǁĞůůƐŚƵƚͲŝŶĨŽƌƚŚĞŶŝŐŚƚĨŽƌƉƌĞƐƐƵƌĞďƵŝůĚƵƉ͘ >ĂǇĚŽǁŶůƵďƌŝĐĂƚŽƌĂŶĚƚŽŽůƐ͘ /ŶƐƚĂůůŶŝŐŚƚĐĂƉŽŶƚŽƉŽĨǁŝƌĞůŝŶĞǀĂůǀĞƐƚŽƐĞĐƵƌĞǁĞůů͘ ^&E ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭͬϱͬϮϮͲtĞĚŶĞƐĚĂǇ zĞůůŽǁ:ĂĐŬĞƚͲůŝŶĞĂƌƌŝǀĞ͘ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ Dh'WddŽŽůƐƚƌŝŶŐ͘ d'W^/ϰϰ /ͬW^/Ϭ dDWϴ͕ ^ǁĂďǀĂůǀĞƐƚĞŵŚŽƵƐŝŶŐǁŽƌŬĞĚůŽŽƐĞĨƌŽŵǀĂůǀĞďŽĚǇ͘ĂůůŽƵƚĨŽƌǀĂůǀĞƌĞƉĂŝƌĂŶĚĨŝǆ͕͘Z/,ǁŝƚŚ'WdĂŶĚƚĂŐŐĞĚƉůƵŐ ĂƚϯϲϮϬΖ͘ ^ĞĞŶƉƌĞƐƐƵƌĞĂŶŽŵĂůǇΕϮϵϱϬŝŶĚŝĐĂƚŝŶŐĨůƵŝĚ͕ďƵƚƉƌĞƐƐƵƌĞƌĞĂĚŝŶŐďĞůŽǁϮϵϱϬΖĚŝĚŶŽƚŝŶĚŝĐĂƚĞĨůƵŝĚůĞǀĞů͘ WKK,͕͘Z/,ǁŝƚŚƐĂŵƉůĞďĂŝůĞƌĂŶĚĐŽůůĞĐƚǁĂƚĞƌƐĂŵƉůĞĂƚϯϬϳϱΖ͘ WƵƚǁĂƚĞƌŝŶƐĂŵƉůĞďŽƚƚůĞĂŶĚƐĞŶĚƚŽZͬ'KŝŶƚŽǁŶ͕͘DhĂŶĚZ/,ǁŝƚŚ'WdĂŶĚƌĞĐŽƌĚĂŶhƉͬŽǁŶƉĂƐƐĂŶĚƐĞŶĚƚŽ 'KͬZ͘ &ůƵŝĚůĞǀĞůĂƉƉĞĂƌƐĐŽŶƐŝƐƚĞŶƚďĞůŽǁϮϴϳϱΖ͕͘>ĂǇĚŽǁŶůƵďƌŝĐĂƚŽƌ͘ >ĞĂǀĞǁŝƌĞůŝŶĞǀĂůǀĞŽŶƚƌĞĞ͕ŝŶƐƚĂůůŶŝŐŚƚĐĂƉ͘ ^ǁĂďǀĂůǀĞĐůŽƐĞĚ͕DĂƐƚĞƌǀĂůǀĞŽƉĞŶƚŽŵŽŶŝƚŽƌƉƌĞƐƐƵƌĞƐ͘ ^&E͘ ϭͬϲͬϮϮͲdŚƵƌƐĚĂǇ d&W^/ϭϬϭ ͬ/W^/Ϭ dDWϭϰ d'W^/ϭϲϬ /ͬW^/Ϭ dDWϵ ϭͬϵͬϮϮͲ^ƵŶĚĂǇ d'W^/ϭϴϱ ͬ/W^/Ϭ dDWϵ ϭͬϳͬϮϮͲ&ƌŝĚĂǇ d'W^/ϭϯϭ ͬ/W^/Ϭ dDWϵ ϭͬϴͬϮϮͲ^ĂƚƵƌĚĂǇ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭͬϭϬͬϮϮͲDŽŶĚĂǇ zĞůůŽǁ:ĂĐŬĞƚͲůŝŶĞĂŶĚ&ŽǆEϮŽŶůŽĐĂƚŝŽŶ͘ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ D/Zh͘ DhͲůŝŶĞ'WdƚŽŽůƐƚƌŝŶŐ͘ dZϮϬϴƉƐŝ /ϬƉƐŝ dDWϭϱ&͖WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ͘ Z/,ǁŝƚŚ'WdĂŶĚĨŝŶĚĨůƵŝĚůĞǀĞůĂƚϭϭϱϬΖ͘ ^ƚĂƌƚƉƵŵƉŝŶŐEϮĂƚϭϬϬϬƐĐĨŵ͘ KŶĐĞƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞƌĞĂĐŚĞƐϮϮϱϬƉƐŝ͕ƌĞĚƵĐĞƌĂƚĞƚŽϱϬϬƐĐĨŵ͘ &ůƵŝĚůĞǀĞůĚƌŽƉƉŝŶŐΕϮϬϬĨƚͬϮϬŵŝŶƵƚĞƐ͖EϮƌĂƚĞĂƚϱϬϬƐĐĨŵ͘^ƵƌĨĂĐĞƉƌĞƐƐƵƌĞсϮϯϯϮƉƐŝ͘ ^ŚƵƚĚŽǁŶEϮƵŶŝƚŽŶĐĞƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞсϮϱϬϬƉƐŝ͘ &ůƵŝĚůĞǀĞůĂƚϮϱϮϬΖ͖͘tĂŝƚŽŶƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞƚŽĚƌŽƉƚŽϮϰϬϬƉƐŝ͘WƌĞƐƐƵƌĞďĂĐŬƵƉŽŶǁĞůůƚŽϮϱϬϬƉƐŝ͘ &ůƵŝĚůĞǀĞůĂƚϮϳϴϬΖ͖͘tĂŝƚŽŶƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞƚŽĚƌŽƉƚŽΕϮϯϱϬƉƐŝ͘WƌĞƐƐƵƌĞďĂĐŬƵƉŽŶǁĞůůƚŽϮϱϬϬƉƐŝ͘ &ůƵŝĚůĞǀĞůĂƚϯϬϴϬΖ͖͘tĂŝƚŽŶƐƵƌĨĂĐĞĨŽƌƉƌĞƐƐƵƌĞƚŽĚƌŽƉƚŽϮϰϬϬƉƐŝ͘WƌĞƐƐƵƌĞďĂĐŬƵƉƚŽϮϱϬϬƉƐŝ͘ &ůƵŝĚůĞǀĞůĂƚϯϯϳϱΖ;ƉĞƌĨƐĂƚϯϯϳϯͲϯϯϴϭΖͿ͘ ^ƵƌĨĂĐĞƉƌĞƐƐƵƌĞсϮϰϳϰƉƐŝ͖͘WKK,ǁŝƚŚ'Wd͘ ůŽƐĞƐǁĂďĂŶĚůĞĂǀĞƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞŽĨϮϰϳϰƉƐŝŽŶǁĞůů͘ ^ĞĐƵƌĞǁĞůůǁŝƚŚŶŝŐŚƚĐĂƉ͘ >&E͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭͬϭϭͬϮϮͲdƵĞƐĚĂǇ zĞůůŽǁ:ĂĐŬĞƚͲůŝŶĞĂŶĚ&ŽǆEϮŽŶůŽĐĂƚŝŽŶ͘ ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ Dh'WdĂŶĚĐŽŽůĚŽǁŶEϮƵŶŝƚ͘ WdůƵďƌŝĐĂƚŽƌƚŽϯϬϬƉƐŝůŽǁͬϯϬϬϬƉƐŝŚŝŐŚ͘ d'ϭϱϯϵ /ϴϬ dDWϮϲ͕^ƚĞƉƌĂƚĞƚĞƐƚǁŝƚŚEϮ͘WƵŵƉĂƚϱϬϬƐĐĨ͕ϳϱϬƐĐĨ͕ϭϬϬϬƐĐĨ͕ϭϮϱϬƐĐĨ͕ϭϱϬϬƐĐĨ͕ϭϳϱϬƐĐĨ͕ϮϬϬϬƐĐĨ͕ϮϮϱϬƐĐĨ͕ϮϱϬϬ ƐĐĨ͘ EŽŝŶĚŝĐĂƚŝŽŶŽĨƉƌĞƐƐƵƌĞďƌĞĂŬŽǀĞƌ͘^ƚĂƌƚŝŶŐƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞĂƚϭϱϮϬƉƐŝ͕ĞŶĚŝŶŐƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞŽĨϮϴϬϬƉƐŝ͘ ,ĂǀĞ'WdŝŶǁĞůůĂƚƉĞƌĨƐƚŽŵŽŶŝƚŽƌƉƌĞƐƐƵƌĞ͘^ƚĂƌƚƉƵŵƉŝŶŐEϮĂƚϱϬϬƐĐĨŵƚŽĚĞƚĞƌŵŝŶĞŝŶũĞĐƚŝǀŝƚǇ͘ ^ƚĂƌƚŝŶŐƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞсϮϯϴϬƉƐŝ͕ƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞĚĞĐůŝŶĞĚƚŽϮϯϲϯƉƐŝ͘ /ŶĐƌĞĂƐĞƚŽϳϬϬƐĐĨŵ͕ƉƌĞƐƐƵƌĞƐƚĂƌƚƐƚŽŝŶĐƌĞĂƐĞƐůŽǁůǇ͕ƵƉƚŽϮϰϬϳƉƐŝŽǀĞƌϮϬŵŝŶƵƚĞƐ͕͘ŝŶĐƌĞĂƐĞƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞƚŽ ϮϲϬϬƉƐŝĂŶĚĨŝŶĚƌĂƚĞƚŽŬĞĞƉƐƚĞĂĚǇt,W͘ ƚϴϬϬƐĐĨŵ͕ƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞŝƐƐƚĂďůĞĂƚϮϱϴϰƉƐŝ͘'WdĚŽǁŶŚŽůĞƉƌĞƐƐƵƌĞсϮϵϭϱƉƐŝ͘ KĨĨůŝŶĞǁŝƚŚEϮ͘ WKK,ǁŝƚŚ'Wd͘DhϯͲϯͬϴΗǆϴΖƉĞƌĨŐƵŶ͘ ůĞĞĚŽĨĨƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞƚŽϭϱϮϭƉƐŝ͕͘Z/,ǁŝƚŚϯͲϯͬϴΗǆϴΖƉĞƌĨŐƵŶ͘ ^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'K͘KŶĚĞƉƚŚ͘ WĞƌĨŽƌĂƚĞϯϯϳϯͲϯϯϴϭΖ;dϭϴͿ /ŶŝƚŝĂůƉƌĞƐƐƵƌĞсϭϱϮϭƉƐŝ͘ ϱŵŝŶсϭϱϮϯƉƐŝ ϭϬŵŝŶсϭϱϮϱƉƐŝ ϭϱŵŝŶсϭϱϮϲƉƐŝ͕WKK,͘ůůƐŚŽƚƐĨŝƌĞĚ͘'ƵŶŝƐĚƌǇ͘>ĂǇĚŽǁŶƚŽŽůƐƚƌŝŶŐ͘^ĞĐƵƌĞǁĞůůǁŝƚŚŶŝŐŚƚĐĂƉ͘>&E͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭͬϭϮͬϮϮͲtĞĚŶĞƐĚĂǇ zĞůůŽǁ:ĂĐŬĞƚĐŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ Dh'WddŽŽůƐƚƌŝŶŐ͘WdůƵďƌŝĐĂƚŽƌ͘ d'W^/ϭϱϰϬ /ͬW^/ϲϬ dDWϯϯ͕Z/,ǁŝƚŚ'WdƚŽũƵƐƚĂďŽǀĞWĞƌĨƐĂƚϯϯϱϬΖ͘tĂŝƚĨŽƌŝŶƚĞƌŶĂůƚĞŵƉƉƌŽďĞƚŽƐƚĂďŝůŝǌĞ͘ dĞŵƉƐƚĂďŝůŝǌĞƐĂƚϲϵĚĞŐ&͘t,WсϭϱϲϴƉƐŝ͕,WсϭϳϲϬƉƐŝ͕͘ŽŵƉƵƚĞƌŽŶzĞůůŽǁ:ĂĐŬĞƚͲůŝŶĞŶŽƚĂďůĞƚŽĂĐƋƵŝƌĞĚĂƚĂ͘ ĂůůƚŽĐŚĂŶŐĞŽƵƚĐŽŵƉƵƚĞƌƐǇƐƚĞŵ͕͘tŝƚŚ'WdŝŶǁĞůůĂƚϯϯϱϬΖ͘KƉĞŶĐŚŽŬĞƚŽĚƌĂǁĚŽǁŶt,WƚŽϭϭϱϬƉƐŝ͘ /ŶŝƚŝĂů͗ǁŚƉсϭϭϱϬƉƐŝ͖ďŚƉсϭϮϵϬƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϱŵŝŶ͗ǁŚƉсϭϭϱϳƉƐŝ͕ďŚƉсϭϮϵϬƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϭϬŵŝŶ͗ǁŚƉсϭϭϱϴƉƐŝ͖ďŚƉсϭϮϵϯƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϮϬŵŝŶ͗ǁŚƉсϭϭϱϵƉƐŝ͕ďŚƉсϭϮϵϲƉƐŝ͕ďŚƚсϳϴĚĞŐ&͕tŝƚŚ'WdŝŶǁĞůůĂƚϯϯϱϬΖ͘KƉĞŶĐŚŽŬĞƚŽĚƌĂǁĚŽǁŶt,WƚŽ ϭϬϮϬƉƐŝ͘ /ŶŝƚŝĂů͗ǁŚƉсϭϬϮϬƉƐŝ͖ďŚƉсϭϭϰϬƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϱŵŝŶ͗ǁŚƉсϭϬϮϲƉƐŝ͕ďŚƉсϭϭϰϱƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϭϬŵŝŶ͗ǁŚƉсϭϬϯϬƉƐŝ͖ďŚƉсϭϭϱϰƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϮϬŵŝŶ͗ǁŚƉсϭϬϯϮƉƐŝ͕ďŚƉсϭϭϱϲƉƐŝ͕ďŚƚсϳϴĚĞŐ&͕tŝƚŚ'WdŝŶǁĞůůĂƚϯϯϳϰΖ;ŝŶƉĞƌĨƐͿ͘KƉĞŶĐŚŽŬĞƚŽĚƌĂǁĚŽǁŶ t,WƚŽϵϭϬƉƐŝ͘ /ŶŝƚŝĂů͗ǁŚƉсϵϭϬƉƐŝ͖ďŚƉсϭϬϯϬƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϱŵŝŶ͗ǁŚƉсϵϭϴƉƐŝ͕ďŚƉсϭϬϯϲƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϭϱŵŝŶ͗ǁŚƉсϵϮϰƉƐŝ͖ďŚƉсϭϬϯϵƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϮϬŵŝŶ͗ǁŚƉсϵϮϲƉƐŝ͕ďŚƉсϭϬϰϱƉƐŝ͕ďŚƚсϳϴĚĞŐ& ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ d'ϱϯϯƉƐŝ /ϬƉƐŝ ϭͬϭϰͬϮϮͲ&ƌŝĚĂǇ d'ϰϰϭƉƐŝ /ϬƉƐŝ ϭͬϭϱͬϮϮͲ^ĂƚƵƌĚĂǇ &ůƵŝĚůĞǀĞůĂƚϯϮϱϬΖ͕tŝƚŚ'WdŝŶǁĞůůĂƚϯϯϳϰΖ;ŝŶƉĞƌĨƐͿ͘KƉĞŶĐŚŽŬĞƚŽĚƌĂǁĚŽǁŶt,WƚŽϴϬϬƉƐŝ͘ /ŶŝƚŝĂů͗ǁŚƉсϴϬϬƉƐŝ͖ďŚƉсϵϬϯƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϱŵŝŶ͗ǁŚƉсϴϬϳƉƐŝ͕ďŚƉсϵϭϭƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϭϬŵŝŶ͗ǁŚƉсϴϭϬƉƐŝ͖ďŚƉсϵϭϲƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϮϬŵŝŶ͗ǁŚƉсϴϭϰƉƐŝ͕ďŚƉсϵϮϮƉƐŝ͕ďŚƚсϳϴĚĞŐ&͕tŝƚŚ'WdŝŶǁĞůůĂƚϯϯϳϰΖ;ŝŶƉĞƌĨƐͿ͘KƉĞŶĐŚŽŬĞƚŽĚƌĂǁĚŽǁŶt,W ƚŽϲϴϬƉƐŝ͘ /ŶŝƚŝĂů͗ǁŚƉсϲϴϬƉƐŝ͖ďŚƉсϳϳϱƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϱŵŝŶ͗ǁŚƉсϲϴϲƉƐŝ͕ďŚƉсϳϳϳƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϭϱŵŝŶ͗ǁŚƉсϲϵϭƉƐŝ͖ďŚƉсϳϴϴƉƐŝ͖ďŚƚсϳϴĚĞŐ& &ůƵŝĚ>ĞǀĞůсϯϮϭϬΖ͕tŝƚŚ'WdŝŶǁĞůůĂƚϯϯϳϰΖ;ŝŶƉĞƌĨƐͿ͘KƉĞŶĐŚŽŬĞƚŽĚƌĂǁĚŽǁŶt,WƚŽϱϬϬƉƐŝ͘ /ŶŝƚŝĂů͗ǁŚƉсϱϬϬƉƐŝ͖ďŚƉсϱϳϰƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϱŵŝŶ͗ǁŚƉсϱϬϳƉƐŝ͕ďŚƉсϱϴϭƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϭϱŵŝŶ͗ǁŚƉсϱϭϮƉƐŝ͖ďŚƉсϱϵϬƉƐŝ͖ďŚƚсϳϴĚĞŐ& &ůƵŝĚ>ĞǀĞůсϯϭϴϲΖ͕tŝƚŚ'WdŝŶǁĞůůĂƚϯϯϳϰΖ;ŝŶƉĞƌĨƐͿ͘KƉĞŶĐŚŽŬĞƚŽĚƌĂǁĚŽǁŶt,WƚŽϯϬϬƉƐŝ͘ /ŶŝƚŝĂů͗ǁŚƉсϯϬϬƉƐŝ͖ďŚƉсϯϱϳƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϱŵŝŶ͗ǁŚƉсϯϬϲƉƐŝ͕ďŚƉсϯϲϬƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϭϱŵŝŶ͗ǁŚƉсϯϭϭƉƐŝ͖ďŚƉсϯϳϬƉƐŝ͖ďŚƚсϳϴĚĞŐ& &ůƵŝĚ>ĞǀĞůсϯϭϯϱΖ͕tŝƚŚ'WdŝŶǁĞůůĂƚϯϯϳϰΖ;ŝŶƉĞƌĨƐͿ͘KƉĞŶĐŚŽŬĞƚŽĚƌĂǁĚŽǁŶt,WƚŽϭϬϬƉƐŝ͘ /ŶŝƚŝĂů͗ǁŚƉсϭϬϬƉƐŝ͖ďŚƉсϭϯϵƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϱŵŝŶ͗ǁŚƉсϭϬϰƉƐŝ͕ďŚƉсϭϰϰƉƐŝ͖ďŚƚсϳϴĚĞŐ& ϭϱŵŝŶ͗ǁŚƉсϭϭϭƉƐŝ͖ďŚƉсϭϱϭ;ĞƐƚŝŵĂƚĞͿƉƐŝ͖ďŚƚсϳϴĚĞŐ& &ůƵŝĚ>ĞǀĞůсϯϬϳϬΖ dĂŐĂƚϯϱϵϮΖ͕WKK,͘ ZDK͘ ϭͬϭϯͬϮϮͲdŚƵƌƐĚĂǇ d'ϮϳϯƉƐŝ /ϬƉƐŝ dDWϮϵ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϭͬϭϲͬϮϮͲ^ƵŶĚĂǇ d'ϱϵϬƉƐŝ /ϬƉƐŝ d'W^/ϳϰϴ ͬ/W^/Ϭ ϬϮͬϭϬͬϮϬϮϮͲdŚƵƌƐĚĂǇ d'W^/ϳϰϲ ͬ/W^/Ϭ ϬϮͬϭϭͬϮϬϮϮͲ&ƌŝĚĂǇ d'W^/ϳϰϳ ͬ/W^/Ϭ ϬϮͬϭϮͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ ϭͬϭϳͬϮϮͲDŽŶĚĂǇ d'ϲϯϰƉƐŝ /ϬƉƐŝ ϭͬϭϴͬϮϮͲdƵĞƐĚĂǇ d'ϲϲϮƉƐŝ /ϬƉƐŝ ϬϮͬϬϳͬϮϬϮϮͲDŽŶĚĂǇ d'W^/ϳϰϴ ͬ/Ϭ ϬϮͬϬϴͬϮϬϮϮͲdƵĞƐĚĂǇ dďŐW^/ϳϰϴ ͬ/W^/Ϭ ϬϮͬϬϵͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ d'W^/ϳϰϰ ͬ/W^/Ϭ ϬϮͬϭϯͬϮϬϮϮͲ^ƵŶĚĂǇ d'W^/ϳϰϰ ͬ/W^/Ϭ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϬϮͬϭϰͬϮϬϮϮͲDŽŶĚĂǇ d'W^/ϳϰϰ ͬ/W^/Ϭ zĞůůŽǁ:ĂĐŬĞƚĂƌƌŝǀĞůŽĐĂƚŝŽŶ͘ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ĂďůĞŽŶĐƌĂŶĞŚĂƐďĞĐŽŵĞĞŶƚĂŶŐůĞĚĂŶĚŶĞĞĚƐƚŽďĞ ĨŝǆĞĚ͘DhĂŶĚZ/,ǁŝƚŚ'WdƚŽŽůƐƚƌŝŶŐ͘dƵďŝŶŐƉƌĞƐƐƵƌĞсϭϲϬϬƉƐŝ͘&ůƵŝĚůĞǀĞůŝƐĂƚϯϰϬϬΖ͘WKK,ĂŶĚůĂǇĚŽǁŶ'Wd ƚŽŽůƐƚƌŝŶŐ͘DhĂŶĚZ/,ǁŝƚŚϳΗ/W͘'Zͬ>ƚŽƚŽƉŽĨƉůƵŐсϭϲ͘ϬΖ͘^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽƚŽǁŶ͘ŽŶĨŝƌŵŽŶĚĞƉƚŚ͘ ,ĂǀĞĂŵŝƐͲĨŝƌĞ͘WKK,ĂŶĚĨŝŶĚďĂĚĐĂƉŽŶƐĞƚƚŝŶŐƚŽŽů͘ZĞƉůĂĐĞĐĂƉŽŶƐĞƚƚŝŶŐƚŽŽůĂŶĚZ/,ǁŝƚŚƉůƵŐ͘^ĞƚƉůƵŐĂƚϯϭϴϬΖ͘ ůĞĞĚƉƌĞƐƐƵƌĞĚŽǁŶĨƌŽŵϭϲϬϬƉƐŝƚŽϴϴϬƉƐŝ͘DhĂŶĚZ/,ǁŝƚŚϯͲϯͬϴΗǆϮϬΖŐƵŶ͘WĞƌĨŽƌĂƚĞdϭϰǌŽŶĞ;ϮϴϵϬͲϮϵϭϬΖͿ͘ /ŶŝƚŝĂůƉƌĞƐƐƵƌĞсϴϴϭƉƐŝ͘ϱŵŝŶƵƚĞсϴϴϰƉƐŝ͘ϭϬŵŝŶƵƚĞсϴϴϰƉƐŝ͘ ϭϱŵŝŶƵƚĞсϴϴϰƉƐŝ͘ůůƐŚŽƚƐĨŝƌĞĚ͘'ƵŶŝƐĚƌǇ͘DhĂŶĚZ/,ǁŝƚŚ'Wd͘ƌĂǁĚŽǁŶǁĞůůƚŽϲϲϰƉƐŝ͘&ůƵŝĚůĞǀĞůсϯϭϭϱƉƐŝ͘ ϭϬŵŝŶƵƚĞďƵŝůĚƵƉƉƌĞƐƐƵƌĞсϲϳϭƉƐŝ͘WKK,ǁŝƚŚ'WdĂŶĚůĂǇĚŽǁŶƚŽŽůƐƚƌŝŶŐ͘^ĞĐƵƌĞǁĞůůǁŝƚŚŶŝŐŚƚĐĂƉ͘ƌĂǁĚŽǁŶ ǁĞůůƚŽϯϬϱƉƐŝ͕ŶŽŐĂƐ͘>ĞĂǀĞƐŚƵƚŝŶĨŽƌƚŚĞŶŝŐŚƚ͘ ϬϮͬϭϳͬϮϬϮϮͲdŚƵƌƐĚĂǇ zĞůůŽǁ:ĂĐŬĞƚͲůŝŶĞĂƌƌŝǀĞ͘ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘dƵďŝŶŐƉƌĞƐƐƵƌĞсϱϮϯƉƐŝ͘ƌĂǁĚŽǁŶǁĞůůƚŽϬƉƐŝ͘ &ůƵŝĚůĞǀĞůсϭϰϵϬΖ͘KďƚĂŝŶǁĂƚĞƌƐĂŵƉůĞ͕͘Zh&ŽǆEϮƵŶŝƚĂŶĚWdƚŽϮϱϬϬƉƐŝ͘WƵŵƉEϮƚŽƉƵƐŚĨůƵŝĚĂǁĂǇ͘DŽŶŝƚŽƌǁŝƚŚ 'WdŝŶǁĞůů͘WƵƐŚĨůƵŝĚƚŽƚŽƉƉĞƌĨĂƚϮϴϵϬΖ͘DhĂŶĚZ/,ǁŝƚŚϳΗ/W͘^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽƚŽǁŶĂŶĚĐŽŶĨŝƌŵŽŶ ĚĞƉƚŚ͘^Ğƚ/WĂƚϮϳϵϬΖ͘^ĞƚĚŽǁŶǁĞŝŐŚƚŽŶƉůƵŐƚŽĐŽŶĨŝƌŵƐĞƚ͘ůĞĞĚƚƵďŝŶŐƉƌĞƐƐƵƌĞĚŽǁŶƚŽϯϱϬƉƐŝ͘DhĂŶĚZ/, ǁŝƚŚϯͲϯͬϴΗǆϭϰΖϲƐƉĨ,^ƉĞƌĨŐƵŶ͘^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'KĂŶĚĐŽŶĨŝƌŵŽŶĚĞƉƚŚ͘WĞƌĨdϭϬǌŽŶĞ;ϮϬϲϰͲϮϬϳϴΖͿ ŝĚŶŽƚŐĞƚƉƌĞƐƐƵƌĞƐĂƚƐƵƌĨĂĐĞƐŝŶĐĞ^^sƚƌŝƉƉĞĚ͘tŝůůŐĞƚƉƌĞƐƐƵƌĞƐĂĨƚĞƌĚŽǁŶůŽĂĚŝŶŐĐƌǇƐƚĂůŐĂƵŐĞĚĂƚĂ͘WKK,͘ ^ŚŽƚƐĨŝƌĞĚ͘'ƵŶŝƐĚƌǇ͘DhƚĂŶĚĞŵĚŽǁŶŚŽůĞŐĂƵŐĞƐŽŶŚĂŶŐĞƌ͘KƉĞŶǁĞůůƚŽŐĂƵŐĞƐĂƚϭϵ͗ϬϴŽŶϮͬϭϳͬϮϮ͘ƐƵƌĨĂĐĞ ƉƌĞƐƐƵƌĞсϳϲϮƉƐŝ͘^ĞŶĚĐŽƌƌĞůĂƚŝŽŶĚĂƚĂƚŽZͬ'KƚŽĐŽŶĨŝƌŵŽŶĚĞƉƚŚ͘^ĞƚĚŽǁŶŚŽůĞƚĂŶĚĞŵŐĂƵŐĞƐĂƚϮϬϱϵΖ͘dŽƉŽĨ ĨŝƐŚŝŶŐŶĞĐŬĂƚϮϬϰϵΖ͘WKK,͘ZDK͘ ϬϮͬϭϴͬϮϬϮϮͲ&ƌŝĚĂǇ d'ϱϱϰƉƐŝ /ϬƉƐŝ dDWϯϰ& ϬϮͬϭϱͬϮϬϮϮͲdƵĞƐĚĂǇ ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘D/ZhzĞůůŽǁ:ĂĐŬĞƚͲůŝŶĞĂŶĚ&ŽǆEϮĞƋƵŝƉŵĞŶƚ͘Dh'WdƚŽŽůƐƚƌŝŶŐ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬ ƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ͘KƉĞŶǁĞůů͘dƵďŝŶŐƉƌĞƐƐƵƌĞсϳϱϬƉƐŝ͘Z/,ĂŶĚĨŝŶĚĨůƵŝĚůĞǀĞůĂƚϭϵϲϬΖ͘Z/,ǁŝƚŚ'WdĂŶĚƉĂƌŬĂƚ ϯϯϲϱΖ͘&ůŽǁǁĞůůǁŝƚŚ'WdƉĂƌŬĞĚĂƚϯϯϲϱΖ͘&ůŽǁǁĞůůĨŽƌĂďŽƵƚϭŚŽƵƌ͕ƚŚĞŶƚƵďŝŶŐƉƌĞƐƐƵƌĞďůĞĚĚŽǁŶƚŽϬƉƐŝ͘ZhEϮ ůŝŶĞƚŽƉƵŵƉŝŶƐƵďĂŶĚWdƚŽϮϱϬϬƉƐŝ͘WƵŵƉEϮĚŽǁŶǁĞůůĂƚϭϬϬϬƐĐĨŵĂŶĚŵĂǆƉƌĞƐƐƵƌĞŽĨϮϱϬϬƉƐŝ͘WƵƐŚĨůƵŝĚƚŽ ϯϭϱϬΖĂŶĚŬĞĞƉϮϱϬϬƉƐŝƚƌĂƉƉĞĚŽŶǁĞůů͘>&E͘ ϬϮͬϭϲͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ d'W^/ϳϲϲ /ͬϮϬ dDWϯϬ ϬϮͬϮϰͬϮϬϮϮͲdŚƵƌƐĚĂǇ d'W^/ϳϱϱ /ͬϮϬ dDWϰϬ ϬϮͬϮϱͬϮϬϮϮͲ&ƌŝĚĂǇ d'W^/ϳϲϰ /ͬϮϬ dDWϰϬ ϬϮͬϮϲͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ d'W^/ϳϯϴ /ͬϱϱ dDWϯϮ& ϬϮͬϮϮͬϮϬϮϮͲdƵĞƐĚĂǇ d'W^/ϳϰϵ /ͬϬ dDWϯϰ& ϬϮͬϮϯͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ d'W^/ϳϱϱ /ͬϮϬ dDWϰϬ ϬϮͬϭϵͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ d'ϱϭϮƉƐŝ /ϱϱƉƐŝ dDWϯϰ& ϬϮͬϮϬͬϮϬϮϮͲ^ƵŶĚĂǇ d'ϰϵϱƉƐŝ /ϱϱƉƐŝ dDWϯϭ ϬϮͬϮϭͬϮϬϮϮͲDŽŶĚĂǇ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ E ϭϭͬϵͬϮϭ ϰͬϯͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ tŚŝƐŬĞǇ'ƵůĐŚϬϭͲŽŵƉůĞƚŝŽŶ ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ ϮϮϭͲϬϰϲ ϬϯͬϬϭͬϮϬϮϮͲdƵĞƐĚĂǇ d'сϳϳϯƉƐŝ /сϮϬƉƐŝ ϬϮͬϮϳͬϮϬϮϮͲ^ƵŶĚĂǇ dďŐͲϳϳϬ /ͲϮϬ dĞŵƉͲϯϱ ϬϮͬϮϴͬϮϬϮϮͲDŽŶĚĂǇ d'сϳϳϭ /сϮϬƉƐŝ ϬϰͬϬϯͬϮϮͲ^ƵŶĚĂǇ ZZ/sdWt>^,KWͲ'd,ZdKK>^EYh/WDEdͲDKdK>Kd/KE ^h^E/KEEͲ:^ͲWZD/dͲd'^D WZd^h^E/KEE&KZt,/^<z'h>, ZZ/sKE>Kd/KEͲ^WKdYh/WDEdͲZ/'hWtͬ>ͲWd>htͬt>>KZͲ'KK Z/,tͬϮ͘ϱΗ:tͬϱ͘ϳΗ>>'h/dKϮϬϰϵΖ<td;ϮK/>:Z>/<^dϭϱϬϬ>^ͿKD&Z WKK,ͲKK,tͬ^dKWE'h'^ Z/'KtEtͬ>Ͳ^hZt>> ϬϯͬϬϮͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ d'сϳϳϯƉƐŝ /сϮϬƉƐŝ ϬϯͬϬϯͬϮϬϮϮͲdŚƵƌƐĚĂǇ d'сϳϳϯƉƐŝ /сϮϬƉƐŝ 2. Facility NameWhiskey GulchPercent100.00%Official Use Authorization SafetyMCFLease UseMCFConservatiMCFWasteMCFReviewed by:COMMISSIONERComm.Comm.19. Remarks:Authorized Name and Digital Signature with date:Heather ChapaSTATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONFACILITY REPORT OF PRODUCED GAS DISPOSITION1. Facility Number 3. Field 4. Operator 5. Month/Year of Disposition231000006 Whiskey Gulch Hilcorp Alaska.LLC February-22Disposition Volume MCF20. For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold0 Pool Name Pool Code7. Reinjected0 Whiskey Gulch 9405008. Flared or vented 1 hour or less47 9. Flared or vented more than 1 hour (see instr.)14630 10. Pilot and Purge0 11. Assist Gas0 13. Other (see instructions)0 14. TOTAL VOLUME (ITEMS 6-13)14677 12. Fuel gas used in lease operations.0 15. NGL Gas Equivalent0 16. Purchased gas0 17. Transferred from:0 18. Transferred to: (Express as a negative #)0 I hereby certify that the foregoing is true and correct to the best of my knowledge.Revision? Date of Revision:Title: Production AnalystContact Phone: 713-209-2469Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235.Contact Email:heather.chapa@hilcorp.comForm 10-422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.govAOGCCDigitally signed by Heather ChapaDN: cn=Heather Chapa, c=US,email=heather.chapa@hilcorp.comDate: 2022.04.08 17:08:38 -05'00'HeatherChapa 10. GAS(BBL)11. OIL(BBL)12. WATER(BBL)13. GAS(BBL)Whiskey Gulch 01 294050080 0 0 14,677Title:Heather Chapa 4/8/2022heather.chapa@hilcorp.comForm 10-405 Rev. 10/2021 20 AAC 25.235I hereby certify that the foregoing is true and correct to the best of my knowledge.14.TOTAL 0Production AnalystRevision? Date of Revision:Authorized Name and Digital Signature with date:Contact Phone:50-231-20079-00-0040713-209-2469Contact Email::6. Days in Oper.STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONMONTHLY PRODUCTION REPORT20 AAC 25.230Name of Operator: HILCORP ALASKA, LLC0Feb-221. Well No. 2. API No.50-XXX-XXXXX-XX-XX3. Type(see instruct.)4. Field & Pool Code5. Method(see instruct.)7. Avg. FTP psig (see instruct.)DAILY AVG. PRODUCTION9. WATER(BBL)TOTAL MONTHLY PRODUCTION8. OIL(BBL)Submit in PDF format to aogcc.reporting@alaska.gov000 14,677Month and Year:AOGCCDigitally signed by Heather ChapaDN: cn=Heather Chapa, c=US,email=heather.chapa@hilcorp.comDate: 2022.04.08 17:09:07 -05'00'HeatherChapa 2. Facility NameWhiskey GulchPercent100.00%Official Use Authorization SafetyMCFLease UseMCFConservatiMCFWasteMCFReviewed by:COMMISSIONERComm.Comm.19. Remarks:Authorized Name and Digital Signature with date:Heather ChapaContact Phone: 713-209-2469Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235.Contact Email:heather.chapa@hilcorp.com18. Transferred to: (Express as a negative #)0 I hereby certify that the foregoing is true and correct to the best of my knowledge.Revision? Date of Revision:Title: Production Analyst15. NGL Gas Equivalent0 16. Purchased gas0 17. Transferred from:0 13. Other (see instructions)0 14. TOTAL VOLUME (ITEMS 6-13)22 12. Fuel gas used in lease operations.0 11. Assist Gas0 9. Flared or vented more than 1 hour (see instr.)10 10. Pilot and Purge0 8. Flared or vented 1 hour or less12 231000006 Whiskey Gulch Hilcorp Alaska.LLC January 2022Disposition Volume MCF20. For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold0 Pool Name Pool Code7. Reinjected0 Whiskey Gulch 940500STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONFACILITY REPORT OF PRODUCED GAS DISPOSITION1. Facility Number 3. Field 4. Operator 5. Month/Year of DispositionForm 10-422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.govAOGCCDigitally signed by Heather ChapaDN: cn=Heather Chapa, c=US,email=heather.chapa@hilcorp.comDate: 2022.04.08 17:12:58 -05'00'HeatherChapa 10. GAS(BBL)11. OIL(BBL)12. WATER(BBL)13. GAS(BBL)Whiskey Gulch 01 2940500800022Title:Heather Chapa 4/8/2022heather.chapa@hilcorp.com8. OIL(BBL)Submit in PDF format to aogcc.reporting@alaska.gov000226. Days in Oper.STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONMONTHLY PRODUCTION REPORT20 AAC 25.230Name of Operator: HILCORP ALASKA, LLC0Jan - 221. Well No. 2. API No.50-XXX-XXXXX-XX-XX3. Type(see instruct.)4. Field & Pool Code5. Method(see instruct.)7. Avg. FTP psig (see instruct.)DAILY AVG. PRODUCTION9. WATER(BBL)TOTAL MONTHLY PRODUCTION50-231-20079-00-0010713-209-2469Contact Email::Form 10-405 Rev. 10/2021 20 AAC 25.235I hereby certify that the foregoing is true and correct to the best of my knowledge.14.TOTAL 0Production AnalystRevision? Date of Revision:Authorized Name and Digital Signature with date:Contact Phone:Month and Year:Form 10-422 Revised 10/2021 20 AAC 25.235Submit in PDF format to aogcc.reporting@alaska.govAOGCCDigitally signed by Heather ChapaDN: cn=Heather Chapa, c=US,email=heather.chapa@hilcorp.comDate: 2022.04.08 17:13:15 -05'00'HeatherChapa 2. Facility NameWhiskey GulchPercent100.00%Official Use Authorization SafetyMCFLease UseMCFConservatiMCFWasteMCFReviewed by:COMMISSIONERComm.Comm.19. Remarks:Authorized Name and Digital Signature with date:Heather ChapaContact Phone: 713-209-2469Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60° F. Authority 20 AAC 25.235.Contact Email:heather.chapa@hilcorp.com18. Transferred to: (Express as a negative #)0 I hereby certify that the foregoing is true and correct to the best of my knowledge.Revision? Date of Revision:Title: Production Analyst15. NGL Gas Equivalent0 16. Purchased gas0 17. Transferred from:0 13. Other (see instructions)0 14. TOTAL VOLUME (ITEMS 6-13)35 12. Fuel gas used in lease operations.0 11. Assist Gas0 9. Flared or vented more than 1 hour (see instr.)35 10. Pilot and Purge0 8. Flared or vented 1 hour or less0 231000006 Whiskey Gulch Hilcorp Alaska.LLC December 2021Disposition Volume MCF20. For production from multiple pools, list contribution of each pool as a percent of Total Volume.6. Sold0 Pool Name Pool Code7. Reinjected0 Whiskey Gulch 940500STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONFACILITY REPORT OF PRODUCED GAS DISPOSITION1. Facility Number 3. Field 4. Operator 5. Month/Year of DispositionForm 10-422 Revised 10/2021 20 AAC 25.235 Submit in PDF format to aogcc.reporting@alaska.govAOGCCDigitally signed by Heather ChapaDN: cn=Heather Chapa, c=US,email=heather.chapa@hilcorp.comDate: 2022.04.08 17:15:15 -05'00'HeatherChapa 10. GAS(BBL)11. OIL(BBL)12. WATER(BBL)13. GAS(BBL)Whiskey Gulch 01 2940500800035Title:Heather Chapa 4/8/2022heather.chapa@hilcorp.com8. OIL(BBL)Submit in PDF format to aogcc.reporting@alaska.gov000356. Days in Oper.STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONMONTHLY PRODUCTION REPORT20 AAC 25.230Name of Operator: HILCORP ALASKA, LLC0Dec - 211. Well No. 2. API No.50-XXX-XXXXX-XX-XX3. Type(see instruct.)4. Field & Pool Code5. Method(see instruct.)7. Avg. FTP psig (see instruct.)DAILY AVG. PRODUCTION9. WATER(BBL)TOTAL MONTHLY PRODUCTION50-231-20079-00-0020713-209-2469Contact Email::Form 10-405 Rev. 10/2021 20 AAC 25.235I hereby certify that the foregoing is true and correct to the best of my knowledge.14.TOTAL 0Production AnalystRevision? Date of Revision:Authorized Name and Digital Signature with date:Contact Phone:Month and Year:AOGCCDigitally signed by Heather ChapaDN: cn=Heather Chapa, c=US,email=heather.chapa@hilcorp.comDate: 2022.04.08 17:15:38 -05'00'HeatherChapa Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/03/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL *CONFIDENTIAL* WHISKEY GULCH 1 (PTD 221-046) Plug/Perf/GPT 2/15/2022 Please include current contact information if different from above. 221-046 T36385 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.04 09:21:48 -09'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 2/04/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WHISKEY GULCH 01 (PTD 221-046) GPT-PERF 01/10/2022 Please include current contact information if different from above. 37' (6HW Received By: 02/07/2022 By Abby Bell at 3:48 pm, Feb 04, 2022 AOGCC Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 2/04/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WHISKEY GULCH 01 (PTD 221-046) GPT-PERF 01/04/2022 Please include current contact information if different from above. 37' (6HW Received By: 02/07/2022 By Abby Bell at 3:48 pm, Feb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y Samantha Carlisle at 8:52 am, Jan 18, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH ; 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Received By: Date: Date: 01/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WHISKEY GULCH 1 (PTD 221-046)**CONFIDENTIAL** GPT-PERF (12/21/2021) Folder Contents (Electronic Plots and Digital Data): Please include current contact information if different from above. Received By: 01/18/2022 37' (6HW By Abby Bell at 9:01 am, Jan 18, 2022 From:Roby, David S (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] Sundry application for Whiskey Gulch 1 (PTD 221-046) Date:Monday, December 6, 2021 10:17:39 AM Dave Roby (907)793-1232 From: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Sent: Tuesday, November 30, 2021 3:02 PM To: Roby, David S (OGC) <dave.roby@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL] Sundry application for Whiskey Gulch 1 (PTD 221-046) Hi Dave 1. Why do we need 90 days of testing: a. The 90 days includes both flowing and shut-in time for WG-01 – estimated online time will be less than 45 days. b. Plan to test 5 sands individually with downhole gauges. i. Each sand: 1 week online, 1 week shut-in and 1 day for well work move to the next sand (15 days total per sand). ii. 5 Sands x 15 days = 75 days iii. 15 additional days to allow for any operation issues or testing adjustments as data is collected. iv. We want to have flexibility in how long we test each sand. If some sands do not perform, then the importance of “proving up” a later sand becomes more important and more flowing data will be desired. Maximum flow duration for any single sand would be 2 weeks. For a hypothetical example: If only one sand is successful, we would flow only it for 2 weeks. If all the sands are successful, we will cut back test length on some/all of the sands to complete the testing within 90 days. c. The flow period will be used to attempt to estimate connected gas volumes in place using P/z. d. The shut-in (PBU) duration will be used to estimate skin, perm, and distance to reservoir boundaries. e. The 90 days encompasses flowing and shut in time and it is the maximum test duration that can potentially be shortened as we get more data. 1. What kind of rates and volumes are you anticipating: a. The flare stack is rated to ~7-8mmscfd. Hypothetically if we flowed 7mmscfd x 45 days this would equal 315 mmscf in volume b. We do not expect WG-01 to be capable of flowing at that high of sustained rates. If I assume an average rate of 4mmscfd x 45 days this equates to 180 mmscf in volume 2. What steps will you take to minimize flaring a. Plan will be to make as quick of decisions as possible regarding the sands productivity, while getting accurate data. This way we can test as many sands as possible within the given timeframe. We will have gauges downhole to get static and flowing data on the sands 3. What, if any, alternatives to flaring the test production did you consider? a. We did discuss different options briefly but flaring is the best path forward for economic evaluation. The only option to take gas to a production facility would be to build a pipeline that would cost millions to build. Further, after Seaview, we want to obtain as accurate of data as possible. Decisions to develop Seaview were made after only a 4 hour flare/well test. As it turned out, those sands had incredibly high decline and were not worth developing for the cost. Had we had the ability or foresight to test these sands for longer, different decisions would have been made. We do not want to repeat that again. Let me know if you have any further questions. We can set up a phone call or meeting with Sierra & Ben (RE and Geo), might be useful to get a full picture of the plans and intentions. Thanks Katherine Katherine O’Connor CIO Operations Engineer Katherine.oconnor@hilcorp.com W: (907) 777-8376 C: (214) 684-7400 From: Roby, David S (CED) <dave.roby@alaska.gov> Sent: Monday, November 22, 2021 11:27 AM To: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Cc: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: [EXTERNAL] Sundry application for Whiskey Gulch 1 (PTD 221-046) Katherine, In the referenced sundry application Hilcorp states there’s no facilities on the WG pad and is requesting authority to test the well for 90 days, presumably since there’s no facilities that means that you’d be flaring the test production for the duration of the 90 days of testing. In order to flare in this situation Hilcorp will need to apply under 20 AAC 25.235(d)(6) for authorization to flare test production ahead of regular production. In order for us to authorize this we’re going to need more information, including: 1. Why do you need 90 days of testing? 2. What kind of rates and volumes are you anticipating? 3. What steps will you take to minimize flaring? 4. What, if any, alternatives to flaring the test production did you consider? Thanks in advance, Dave Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. 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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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y Samantha Carlisle at 9:03 am, Nov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dts 12/3/2021 12/3/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.12.03 09:49:27 -09'00' RBDMS HEW 12/7/2021 Well Work Prognosis VER2 Well Name: Whiskey Gulch 01 API Number: 50-231-20079-00-00 Current Status: Leg: N/A Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 221-046 First Call Engineer: Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 First Call Engineer: Ryan Rupert Cell: 907-301-1736 Max Expected BHP: 2292 psi @ 5331’ TVD 0.433 psi/ft gradient to surface Well History: Whiskey Gulch -01 is an exploration well drilled near Ninilchik into the Tyonek gas sands. It was drilled in August of 2021. The lower part of the wellbore was abandoned when drilling deeper did not find any oil sands. It was abandoned and liner cemented in place. The current plan is to pull the 4.5” kill string and blow the well dry with N2 to prep for future perforations. Overall plan forward is to isolate and test the Tyonek gas sands. There are no facilities on Whiskey Gulch pad. All the sands are normally pressured (0.43 psi/ft gradient), and the well was left fluid packed with 6% KCl (8.65# fluid = 0.45 psi/ft). Once testing is done, this well will be completed with tubing and a packer (sundry to be submitted at a later date). Last Casing Test: x 7-5/8” casing tested to 3500 psi under PTD 221-046 on 8/26/21 Waiver Request: x Hilcorp requests a waiver to 20AAC25.265(c)(1). We request to locate the SSV on the tree wing allowing the SSV to remain in the production stream while providing concurrent wellbore access. x Hilcorp requests a variance to 20 AAC 25.285 to pull the tubing without BOPs. This well is unperforated and the 7- 5/8” casing passes a pressure test to 3500 psi. x 10-3/4” x 7-5/8” annulus will not pass a pressure test and has too little leak off rate for a down squeeze, Hilcorp requests waiver to to 20 AAC 25.200(d) to produce this well without a production packer for 90 days. o The well has too little leakoff for a downsqueeze. To get cement isolation, it would require punching holes in the tubing for an upsqueeze. Over the life of the well, that adds more risk to production. o The IA will be monitored for the duration of the flow testing for pressure and signs of communication with the producing zones which might indicate a channel in the cement. If pressure builds up on the IA, bleed it to check for the presence of gas. Procedure: ϭ͘Circulate ±10 bbls of 6% KCl Ϯ͘24 hours before rigging up on the well, bleed the IAP down to 0 psi and verify no pressure build up in the 24 hour period. ϯ͘Perform no fůŽǁƚĞƐƚ on the well per state regulations. ϰ͘MIRU and spot crane Ă͘Ensure pump truck is on location to pump and access to fluids ϱ͘ND tree, BOLDS ϲ͘Unseat 4.5” tubing hanger, ϳ͘Install slips ϴ͘Pull 4.5” kill string (11 joints), monitoring hole volume & pipe displacement. Ă͘Keep hole full & fluid packed as pipe is pulled. ϵ͘NU 7-5/8” tree ϭϬ͘Test tree to 5,000 psi ϭϭ͘MIRU Coil tubing ƉƉƌŽǀĞĚͲďũŵ ƉƉƌŽǀĞĚͲďũŵ /ĨŐĂƐŝƐŽďƐĞƌǀĞĚŝŶƚŚĞ/͕ĂƌĞŵĞĚŝĂůĐĞŵĞŶƚũŽďŵƵƐƚďĞ ƉĞƌĨŽƌŵĞĚďĞĨŽƌĞĐŽŶƚŝŶƵŝŶŐŽƉĞƌĂƚŝŽŶƐĐŽǀĞƌĞĚŝŶƚŚŝƐƐƵŶĚƌǇ͘ ŶŽƚŚĞƌƐƵŶĚƌǇǁŝůůďĞƌĞƋƵŝƌĞĚĨŽƌƌĞŵĞĚŝĂůĐĞŵĞŶƚŝŶŐ͘ďũŵ ϭϬŵŝŶƵƚĞĨůŽǁĐŚĞĐŬƚŽǀĞƌŝĨǇǁĞůůŝƐĚĞĂĚŝƐƐƵĨĨŝĐŝĞŶƚ͘ ďũŵ ƉƉƌŽǀĞĚͲďũŵ Well Work Prognosis VER2 12. Test BOPs to 250 psi low/2500 psi high (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test) a. Blow the well dry with N2 13. RDMO coil tubing 14. MIRU EL, PT lubricator to 250 psi low/2500 psi high 15. Perforate and test the intervals (see schematic for specific perf depths) a. If the IA shows any signs of pressurization during perforating & flowing the well, immediately shut in the well, bleed the IAP and monitor for TBG x IA communication. If there is suspected communication, contact Katherine O’Connor and do not resume operations. 16. Install crystal gauges near perforated interval. Record tubing pressures before and after each perforating run. 17. Nitrogen may be used to pressure up the well or to push water away in the event a wet interval is encountered. 18. Intervals will be tested individually. After testing the sand, a plug will be set to ensure isolation between zones. 19. Intervals will be tested through a test separator and flared through a portable flare stack. 20. Once the final perforations have been added and tested & the well is shut in, bleed the IAP pressure down to 0 psi. After a 24 hour period verify there has been no pressure build up. Attachments 1. Current Schematic 2. Proposed Schematic 3. Proposed wellhead schematic 4. N2 Procedure 5. 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ϭϬ͘ dĞƐƚƚƌĞĞƚŽϱ͕ϬϬϬƉƐŝ ϭϭ͘ D/ZhŽŝůƚƵďŝŶŐ ϭϮ͘ dĞƐƚKWƐƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ;EŽƚĞ͗EŽƚŝĨǇK'ϰϴŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚƚŽĂůůŽǁƚŚĞŵƚŽ ǁŝƚŶĞƐƐƚĞƐƚͿ Ă͘ ůŽǁƚŚĞǁĞůůĚƌǇǁŝƚŚEϮ ϭϯ͘ ZDKĐŽŝůƚƵďŝŶŐ ϭϰ͘ D/Zh>͕WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϮϱϬϬƉƐŝŚŝŐŚ ϭϱ͘ WĞƌĨŽƌĂƚĞĂŶĚƚĞƐƚƚŚĞŝŶƚĞƌǀĂůƐ;ƐĞĞƐĐŚĞŵĂƚŝĐĨŽƌƐƉĞĐŝĨŝĐƉĞƌĨĚĞƉƚŚƐͿ ϭϲ͘ /ŶƐƚĂůůĐƌǇƐƚĂůŐĂƵŐĞƐŶĞĂƌƉĞƌĨŽƌĂƚĞĚŝŶƚĞƌǀĂů͘ZĞĐŽƌĚƚƵďŝŶŐƉƌĞƐƐƵƌĞƐďĞĨŽƌĞĂŶĚĂĨƚĞƌĞĂĐŚƉĞƌĨŽƌĂƚŝŶŐƌƵŶ͘ 6XSHUVHGHG 5HYLHZ 1 VDIHW\ SURFHGXUHV EHIRUH SXPSLQJ 1 7KHUH VKRXOG EH VWDWHPHQW LQDQ\ SURJUDP ZKHUH 1 LV SXPSHG SHU DJUHHPHQW IROORZLQJ +LOFRUS 1 LQFLGHQW EMP tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ ϭϳ͘ EŝƚƌŽŐĞŶŵĂǇďĞƵƐĞĚƚŽƉƌĞƐƐƵƌĞƵƉƚŚĞǁĞůůŽƌƚŽƉƵƐŚǁĂƚĞƌĂǁĂǇŝŶƚŚĞĞǀĞŶƚĂǁĞƚŝŶƚĞƌǀĂůŝƐ ĞŶĐŽƵŶƚĞƌĞĚ͘ƉůƵŐŵĂǇĂůƐŽďĞƐĞƚƚŽĞůŝŵŝŶĂƚĞƚŚĞŝŶĨŝůƚƌĂƚŝŽŶŽĨǁĂƚĞƌĨƌŽŵĂǁĞƚǌŽŶĞ͘ ϭϴ͘ /ŶƚĞƌǀĂůƐŵĂǇďĞƚĞƐƚĞĚŝŶĚŝǀŝĚƵĂůůǇŽƌŝŶĐŽŶũƵŶĐƚŝŽŶǁŝƚŚĂŶŽƚŚĞƌŝŶƚĞƌǀĂů͘ ϭϵ͘ /ŶƚĞƌǀĂůƐǁŝůůďĞƚĞƐƚĞĚƚŚƌŽƵŐŚĂƚĞƐƚƐĞƉĂƌĂƚŽƌĂŶĚĨůĂƌĞĚƚŚƌŽƵŐŚĂƉŽƌƚĂďůĞĨůĂƌĞƐƚĂĐŬ͘ ƚƚĂĐŚŵĞŶƚƐ ϭ͘ ƵƌƌĞŶƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ WƌŽƉŽƐĞĚǁĞůůŚĞĂĚƐĐŚĞŵĂƚŝĐ ϰ͘ EϮWƌŽĐĞĚƵƌĞ ϱ͘ dĨůŽǁƐĐŚĞŵĂƚŝĐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ĚŝƚĞĚǇ͗:ϬϵͲϯϬͲϮϬϮϭ WƌŽƉŽƐĞĚ ^ĐŚĞŵĂƚŝĐ tĞůů͗tŚŝƐŬĞǇ'ƵůĐŚϭ Wd͗ϮϮϭͲϬϰϲ W/͗ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ dсϭϬ͕Ϯϳϭ͛ ;DͿͬ dсϵ͕ϯϯϮ͛;dsͿ ϭϲ͟ KƌŝŐ͘<ůĞǀ͗͘ϭϴ͛ͬ'>ůĞǀ͗͘ϮϬϮ͘ϲ͛ ϳͲϱͬϴ͟ ϭϬͲϯͬϰ͟ Wdс ϳ͕ϰϬϰ͛;DͿͬWdс ϲ͕ϱϬϴ͛;dsͿ ϰͲϭͬϮ͟ ϲͲϯͬϰ͟,ŽůĞ ϵͲϳͬϴ͟,ŽůĞ ϭϯͲϭͬϮ͟,ŽůĞ dK ƚĂŐŐĞĚΛ ϳϰϬϰ͛D ^/E'd/> ^ŝǌĞ dǇƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌʹƌŝǀĞŶ ƚŽ^ĞƚĞƉƚŚ ϴϰ yͲϱϲ tĞůĚ ϭϱ͘Ϭϭ͟ ^ƵƌĨ ϭϮϬ͛ ϭϬͲϯͬϰ͟ ^ƵƌĨƐŐ ϰϱ͘ϱ >ͲϴϬ tͬ ϵ͘ϵϱϬ͟ ^ƵƌĨ ϭ͕ϱϬϭ͛ ϳͲϱͬϴΗ /Ŷƚ͘ƐŐ Ϯϵ͘ϳ >ͲϴϬ ϲ͘ϴϳϱ͟ ^ƵƌĨ ϳ͕ϳϬϮ͛ ϰͲϭͬϮΗ ďĂŶĚŽŶŵĞŶƚ>Ŷƌ ϭϮ͘ϲ >ͲϴϬ /d ϯ͘ϵϱϴ͟ ϳ͕ϱϯϴ͛ ϭϬ͕Ϯϲϴ͛ ϰͲϭͬϮΗ <ŝůů^ƚƌŝŶŐ ϭϮ͘ϲ >ͲϴϬ /d ϯ͘ϵϱϴ͟ ^ƵƌĨ ϱϰϭ͛ :t>Zzd/> EŽ͘ ĞƉƚŚ / K /ƚĞŵ ϭ ϭ͕ϮϮϬ͛ ϲ͘ϴϳϱ͟ ϵ͘ϵϱϬ͟ ϳͲϱͬϴ͟^ǁĞůůWĂĐŬĞƌ Ϯ ϳ͕ϱϯϴ͛ ϭ͘ϴϳϱ͟ ϰ͘ϱϬϬ͟ ,ĂůůŝďƵƌƚŽŶ,<ŝƐĐŽŶŶĞĐƚdŽŽů KWE,K>ͬDEdd/> ϭϬͲϯͬϰ͟ Ɛƚ͘dKΛ^ƵƌĨĂĐĞ;ϭϬϬйĞǆĐĞƐƐͿZĞƚƵƌŶƐƚŽƐƵƌĨĂĐĞ;ϴͬϭϮͬϮϭͿ ϳͲϱͬϴΗ Ɛƚ͘dKΛΕϭϰϯϬ͛;>ĐŽŶĚƵĐƚĞĚϴͬϮϵͬϮϭ;ϰϬйĞǆĐĞƐƐͿ ϰͲϭͬϮ͟ dKΛϳ͕ϰϬϰ;dĂŐŐĞĚͿ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ĚŝƚĞĚǇ͗ZZϭϬͲϮϵͲϮϬϮϭ WZKWK^tĞůů͗tŚŝƐŬĞǇ'ƵůĐŚϭ Wd͗ϮϮϭͲϬϰϲ W/͗ϱϬͲϮϯϭͲϮϬϬϳϵͲϬϬͲϬϬ WZ&KZd/KEd/> ŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ dϴ цϭ͕ϵϱϬ͛ цϭ͕ϵϳϬ͛ цϭ͕ϴϴϭ͛ цϭ͕ϵϬϭ͛ цϮϬ͛&hdhZWƌŽƉŽƐĞĚ dϭϬ цϮ͕Ϭϲϰ͛ цϮ͕Ϭϳϴ͛ цϭ͕ϵϳϲ͛ цϭ͕ϵϵϬ͛ цϭϰ͛&hdhZWƌŽƉŽƐĞĚ dϭϬͺ цϮ͕Ϯϱϲ͛ цϮ͕ϮϲϮ͛ цϮ͕ϭϯϲ͛ цϮ͕ϭϰϮ͛ цϲ͛&hdhZWƌŽƉŽƐĞĚ dϭϭ цϮ͕ϰϭϴ͛ цϮ͕ϰϯϴ͛ цϮ͕Ϯϲϵ͛ цϮ͕Ϯϴϵ͛ цϮϬ͛&hdhZWƌŽƉŽƐĞĚ dϭϮ цϮ͕ϲϮϬ͛ цϮ͕ϲϱϬ͛ цϮ͕ϰϯϯ͛ цϮ͕ϰϲϯ͛ цϯϬ͛&hdhZWƌŽƉŽƐĞĚ dϭϯ цϮ͕ϲϵϲ͛ цϮ͕ϳϬϮ͛ цϮ͕ϰϵϱ͛ цϮ͕ϱϬϭ͛ цϲ͛&hdhZWƌŽƉŽƐĞĚ dϭϯ>ŽǁĞƌ цϮ͕ϳϱϲ͛ цϮ͕ϳϲϳ͛ цϮ͕ϱϰϰ͛ цϮ͕ϱϱϱ͛ цϭϭ͛&hdhZWƌŽƉŽƐĞĚ dϭϰ цϮ͕ϴϭϴ͛ цϮ͕ϴϯϯ͛ цϮ͕ϱϵϰ͛ цϮ͕ϲϬϵ͛ цϭϱ͛&hdhZWƌŽƉŽƐĞĚ dϭϰ цϮ͕ϴϵϬ͛ цϮ͕ϵϭϳ͛ цϮ͕ϲϱϯ͛ цϮ͕ϲϴϬ͛ цϮϳ͛&hdhZWƌŽƉŽƐĞĚ dϭϲ цϯ͕ϭϬϱ͛ цϯ͕ϭϮϬ͛ цϮ͕ϴϮϳ͛ цϮ͕ϴϰϮ͛ цϭϱ͛&hdhZWƌŽƉŽƐĞĚ dϭϴ цϯ͕ϯϳϯ͛ цϯ͕ϯϴϭ͛ цϯ͕Ϭϰϱ͛ цϯ͕Ϭϱϯ͛ цϴ͛&hdhZWƌŽƉŽƐĞĚ dϭϵ цϯ͕ϰϳϭ͛ цϯ͕ϰϴϵ͛ цϯ͕ϭϮϱ͛ цϯ͕ϭϰϯ͛ цϭϴ͛&hdhZWƌŽƉŽƐĞĚ dϮϬ цϯ͕ϲϰϬ͛ цϯ͕ϲϳϮ͛ цϯ͕ϮϲϮ͛ цϯ͕Ϯϵϰ͛ цϯϮ͛&hdhZWƌŽƉŽƐĞĚ dϯϬ цϯ͕ϵϲϵ͛ цϯ͕ϵϳϴ͛ цϯ͕ϱϮϵ͛ цϯ͕ϱϯϴ͛ цϵ͛&hdhZWƌŽƉŽƐĞĚ dϯϬ цϰ͕ϬϬϰ͛ цϰ͕ϬϬϴ͛ цϯ͕ϱϱϴ͛ цϯ͕ϱϲϮ͛ цϰ͛&hdhZWƌŽƉŽƐĞĚ dϰϴ цϰ͕ϰϴϮ͛ цϰ͕ϱϳϵ͛ цϯ͕ϵϱϮ͛ цϰ͕Ϭϰϵ͛ 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WƵŵƉŶŝƚƌŽŐĞŶĂƚĚĞƐŝƌĞĚƌĂƚĞ͕ŵŽŶŝƚŽƌŝŶŐƌĂƚĞ;^&DͿĂŶĚƉƌĞƐƐƵƌĞ;W^/Ϳ͘ůůŶŝƚƌŽŐĞŶƌĞƚƵƌŶƐ ĂƌĞƚŽďĞƌŽƵƚĞĚƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘ ϭϱ͘Ϳ tŚĞŶĨŝŶĂůŶŝƚƌŽŐĞŶǀŽůƵŵĞŚĂƐďĞĞŶĂĐŚŝĞǀĞĚ͕ŝƐŽůĂƚĞǁĞůůĨƌŽŵEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ ďůĞĞĚĚŽǁŶůŝŶĞƐďĞƚǁĞĞŶǁĞůůĂŶĚEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϲ͘Ϳ KŶĐĞǇŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞǆŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϳ͘Ϳ &ŝŶĂůŝǌĞũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞDĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶǇůĞƐƐŽŶƐůĞĂƌŶĞĚ ĂŶĚĐŽŶĨŝƌŵĨŝŶĂůƌĂƚĞƐͬƉƌĞƐƐƵƌĞͬǀŽůƵŵĞƐŽĨƚŚĞũŽďĂŶĚƌĞŵĂŝŶŝŶŐŶŝƚƌŽŐĞŶŝŶƚŚĞƚƌĂŶƐƉŽƌƚ͘ ϭϴ͘Ϳ ZDKEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ &RLOHG7XELQJ%23 6:$%9$/9( 0$67(59$/9( +LOFRUS )ORZ'LDJUDP )OXLGV3XPSHG )OXLGV5HWXUQHG 9DOYH2SHQ 9DOYH&ORVHG *DWH 9DOYH %DOO9DOYH %XWWHUIO\9DOYH /R7RUT9DOYH $XWRPDWLF&KRNH 0DQXDO&KRNH 3UHVVXUH*DXJH.QLIH9DOYH Choke Line P PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLD GAS BUSTER Panic Line C12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C :KHUH LV WKH IODUH VWDFN" David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/11/2021 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WHISKEY GULCH 1 (PTD 221-046) **CONFIDENTIAL** EXTENDED MICRO IMAGER (XRMI) RUN 3 RAW DATA RUN 3 FINAL INTERPRETATIONS RUN 3 PROCESSESSING DATE: 10/05/2021 RUN 3 LOGGING DATE: 08/29/2021 Folder Contents (Electronic Plots and Digital Data): Please include current contact information if different from above. Received By: 11/12/2021 37' (6HW By Abby Bell at 9:26 am, Nov 12, 2021 AOGCC David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/11/2021 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WHISKEY GULCH 1 (PTD 221-046) **CONFIDENTIAL** EXTENDED MICRO IMAGER (XRMI) RUN 2 RAW DATA RUN 2 FINAL INTERPRETATIONS RUN 2 PROCESSESSING DATE: 09/23/2021 RUN 2 LOGGING DATE: 08/22/2021 Folder Contents (Electronic Plots and Digital Data): Please include current contact information if different from above. Received By: 11/12/2021 37' (6HW By Abby Bell at 9:27 am, Nov 12, 2021 AOGCC From:Guhl, Meredith D (CED) To:Cody Dinger; David Douglas Cc:Davies, Stephen F (CED); Boyer, David L (CED); McLellan, Bryan J (CED) Subject:RE: [EXTERNAL] Whiskey Gulch 1 Date:Wednesday, October 6, 2021 12:52:00 PM Hi Cody, Logs and data submitted to date look good, thank you for providing the complete list. The AOGCC has received everything run in WG1 so far. Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Cody Dinger <cdinger@hilcorp.com> Sent: Thursday, September 30, 2021 9:52 AM To: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Cc: David Douglas <David.Douglas@hilcorp.com> Subject: RE: [EXTERNAL] Whiskey Gulch 1 Hi Meredith, I inquired with David Douglas prior to submittal and this is what we ran in WG 1: Cutting/Samples were sent on 8/28/2021 MUDLOGS - EOW DRILLING REPORTS (08/09/2021 to 08/28/2021) 1. DAILY DRILLING REPORTS 2. FINAL EOW REPORT 3. DIGITAL DATA 4. LWD LOG PRINTS 5. MUDLOG PRINTS 6. SAMPLE PHOTOS 7. SHOW REPORTS FINAL LWD FORMATION EVALUATION LOGS (08/09/2021 to 08/28/2021) 1. DGR, GM, EWR-5, ADR, ALD, CTN (2” & 5” MD/TVD Color Logs) 2. Final Definitive Directional Survey FINAL OPEN HOLE WIRELINE LOGS Run 1 (08/11/2021) Run 2 (08/22/2021) Run 3 (08/29/2021) 1. BOREHOLE VOLUME (RUN 1 & 2: 08/11 & 22/2021) 2. BOREHOLE VOLUME (RUN 3: 08/29/2021) 3. ROTARY SW CORE TOOL (RUN 3: 08/29/2021) 4. WAVEFORM SONIC RAW & PROCESSED (RUN 1: 08/11/2021) 5. WAVEFORM SONIC RAW & PROCESSED (RUN 2: 08/22/2021) 6. WAVEFORM SONIC RAW & PROCESSED (RUN 3: 08/29/2021 7. EXT RANGE MICRO IMAGER RAW & PROCESSED (RUN 1 & 2: 08/11 & 22/2021) 8. EXT RANGE MICRO IMAGER RAW & PROCESSED (RUN 3: 08/29/2021) CASED HOLE LOGS: 1. Cement Bond Log (08/29/2021) Highly likely that some perf/tie in logs will be run during the completion/testing phase of this well. If there any logs outstanding – please contact David Douglas and he can true up any missing logs. Thank you! Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 From: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Sent: Thursday, September 30, 2021 9:45 AM To: Cody Dinger <cdinger@hilcorp.com> Subject: [EXTERNAL] Whiskey Gulch 1 Hi Cody, Do you have a list of logs run on Whiskey Gulch 1 so far? Even though it’s not a 407, I like to review the data to make sure we have received everything. Sometimes things fall through the cracks with exploration wells. Thanks, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 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. 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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory 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 10,271 feet 7,404 feet true vertical 9,332 feet N/A feet Effective Depth measured 7,404'feet 1,220'feet true vertical 6,508'feet 1,214'feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth)4-1/2" L-80 541' 541' Packers and SSSV (type, measured and true vertical depth)N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Contact Email: Contact Phone:907-777-8413 Authorized Name: Monty Myers Authorized Title: Drilling Manager Hilcorp Alaska LLC 2. Operator Name N/A 5,210psi 8,430psi Senior Engineer:Senior Res. Engineer: N/A Collapse N/A 2,470psi 7,500psi Burst 120' 1,488' 6,805' 9,331'N/A 16" 10-3/4" 7-5/8" Length 120' 1,501' Conductor Surface Intermediate Production Casing Structural Liner (P&A'd)2,730' 5. Permit to Drill Number: N/A Whiskey Gulch ProspectSubmitted Separately measured 7,702' 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf N/A Authorized Signature with date: Frank Roach Frank.roach@hilcorp.com N/A Casing Pressure Tubing Pressure ADL392666 8/30/21- Cement 6-3/4" hole; 4-1/2" liner run to 10,268' MD pump 128bbls15.3 ppg cmt Disconnect from liner Tagged @ 7,404' MD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-438 N/A Size Whiskey Gulch 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 221-046 50-231-20079-00-00 4. Well Class Before Work: Plugs Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: N/A Representative Daily Average Production or Injection Data N/AN/A N/A Oil-Bbl measured true vertical Packer 4-1/2" 7,702' WINJ WAG N/A Water-Bbl MD 120' 1,501' 10,268' TVD t Fra O Ot 6. A G L PG 50 0, R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations 9.30.2021Digitally 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: 2021.09.30 09:24:54 -08'00' Monty M Myers By Meredith Guhl at 9:32 am, Sep 30, 2021 DSR-9/30/21 RBDMS HEW 9/30/2021 SFD 10/5/2021 G BJM 10/25/21 _____________________________________________________________________________________ EditedBy: CJD09-30-2021 Proposed Schematic Well: Whiskey Gulch 1 PTD: 221-046 API: 50-231-20079-00-00 CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 X-56 Weld 15.01”Surf 120’ 10-3/4”Surf Csg 45.5 L-80 DWC/C 9.950”Surf 1,501’ 7-5/8"Int. Csg 29.7 L-80 CDC 6.875”Surf 7,702’ 4-1/2"Abandonment Lnr 12.6 L-80 IBT 3.958”7,538’10,268’ 4-1/2"Kill String 12.6 L-80 IBT 3.958”Surf 541’ JEWELRY DETAIL No.Depth ID OD Item 1 1,220’6.875”9.950”7-5/8” Swell Packer 2 7,538’1.875”4.500”Halliburton BHKA Disconnect Tool OPEN HOLE / CEMENT DETAIL 10-3/4”Est. TOC @ Surface (100% excess) Returns to surface (8/12/21) 7-5/8"Est. TOC @ ~1430’(CBL conducted 8/29/21 (40% excess) 4-1/2”TOC @ 7,404 (Tagged) BJM Activity Date Ops Summary 7/30/2021 On Seaview Pad, cont to RD lights, spool up cords and prep mods for tear out. RD Handy Berm, sent half the night crew to Whiskey pad to lay out felt, liner and rig mats. Crane on location at 07:30 and first truck. Tore out boiler skid, lowered pit roofs. Spotted crane and removed clam shell.;More trucks at 09:00, tore out catwalk, aux fuel tank, pump skid #2, pit #3, pump skid #1, picked centrifuge off it's stand then picked choke house off outriggers. Tore out gen skid, pit's 2 and 1 and poorboy degasser skid. Layed derrick down. Transported oversize loads to Whiskey pad.;Tore out HPU skid, lowered dog house and tore out same. Spotted 2nd crane, removed derrick house and layed down windwalls, Picked iron roughneck off floor and layed down V door windwall. RU and picked derrick off carrier, picked carrier off sub, picked sub off pony walls. Loaded pony walls and;transported all to Whiskey pad. Offloaded and set pony walls, staged cranes and set sub on pony walls, centered up over wellhead. Stood V door wall, flew iron roughneck to rig floor. transported carrier to Whiskey pad.;Set carrier on sub, set and pinned derrick on carrier, stood derrick windwalls and set derrick house. Set HPU skid, gen skid, doghouse/water tank. Raised doghouse and start RU of that. Stacked rig mats on Seaview pad, clean up liner with vac truck, cut and dispose of liner/felt.;Cont RU air lines and electric to doghouse, install lights on roof tops, hook up jumper hoses and electric cords to pits and pump skids, set service shacks, powered up gen skid and got rig lit up, prepped and stood mast, raised all three pit roof's, raised vac degasser in pit 4, took on rig water. 7/31/2021 Install equalizer lines between pit modules, set clam shell and choke house with crane, set poorboy degasser skid, aux fuel tank and boiler skid. RD office trailers and change shack on seaview pad, transport those to whiskey pad.;Sleeper trailer took out a low hanging phone line on old sterling highway. CCI Supervisor and DOT were notified. Trailer height was lower than max permitted height. Set centrifuge on stand, spotted the 4 trailers, change shack and shop.;Set bang board and gen set, installed vent line on poorboy degasser, stood degasser vessel and RU same, brought in rig loader and BOP's on cradle. Wired in and powered up trailers. Handy Berm bermed in entire rig footprint.;spooled drill line on drum, bridled up and scoped up derrick, set upright water tank, installed standpipe manifold, hung lower torque tube, installed "T" bar and turnbuckles, hung torque bushing, staged topdrive on catwalk and worked to rig floor.;Pinned topdrive to blocks and removed cradle, Installed new bushings in extend arm pin eyes, staged diverter equipment for RU, organized yard and mud dock, changed topdrive swivel and gear box oil. Installed service loop and kelly hose.;Installed HP jumper from pump to sub, installed suction lines from pits to pumps. Set hurricane vac unit.;Changed pump #2 back to 5 1/2" swabs/liners, RU centrifuge and removed shipping blocks, installed shaker slides, hung rig tongs, staged subs, XO's and safety valves on rig floor, set wear ring/test plug in wellhead, RU iron roughneck HPU and function tested same.;Bump test agitators and hoppers, RU Pason weight indicator and depth tracker. 8/1/2021 Installed PVT sensor in upright water tank, RU electric choke and function tested, Obtained RKB’s, Installed DSA, spacer spool, diverter T, annular, flow riser and knife valve.;Torque up diverter bolts, installed vent line out Drillers side of catwalk, bolted and anchored same, staged well on diverter signage. Re-shimed topdrive extend arms, replaced bent load collar adjusting screw on offside of topdrive, rebuilt HCR for spare,;replaced the raising cylinder on iron roughneck and top mounting plate. Received 30 yard dumpsters, checked end play on quill shaft and gear box back lash on topdrive. Cont hauling rig mats off seaview pad.;Cont hauling last of rig mats off seaview pad. Installed flowline to shakers, hung bales and elevators, installed hyd fittings on annular and tied in koomey lines, circulated water through charge pumps, hoppers, gun lines and checked PVT alarms. Oil change on changeshack gen.;Cont rig acceptance checklist, cont testing PVT alarms in pits, RU gai-tronics, function test trip tank pump and mud pumps, Changed out Drillers side hyd winch cable. 8/2/2021 PU 4 1/2" test joint and set in annular, function tested knife valve and annular, LD test joint, function tested eaton brake high and low, RU skate house and function tested catwalk/skate, set mud pump popoff’s at 3400 psi, checked pulsation dampeners, cont cleaning and disinfecting rig modules.;Got comm’s up and running. Sent all hands getting off tour for covid testing, all hands coming on tour also tested. Had CCI rig support go in for testing. Four rig hands tested positive, only one with symptoms. Painted diverter vent line. Shipped out Baker, Weatherford and Yellow Jacket tools.;Sent CCI Rep to Seaview Pad, to decontaminate electrical room front door, door knob and lock keypad (used for sending reports last couple days), organized pad to make room for incoming surface casing, walked entire berm of pad to repair any loader or truck tire ruts created during rig up.;Completed PM's on iron roughneck, rig hydraulics, catwalk, boiler, rig floor hyd winches, draw works brakes. Disinfected and weekly inspected company trucks, prep to test spare HCR's and manual valve. 8/3/2021 Test two HCR's and one manual valve (spares) at 250/3500 psi. cont working rig acceptance checklist, prep spot for casing rack, clean and organize HPU connex and pump rooms.;Sent two hands to replace blank cap with cap/valve on 4" conductor outlet on Seaview 9. Received total 42 joints 10 3/4" surface casing, including shoe track, pulled protectors and drifted same at 9.87" , re-installed protectors. Received landing joint/hanger and two 13 1/2" tri-cone bits;with bit breaker. Power washed rig floor, A legs, inner windwalls, draw works, pump rooms and mud dock area. Troubleshot Pason system.;Cont troubleshooting Pason, CCI removed plywood sound barrier from south fence on Seaview pad. Set up containment next to pit 3 to park dragon wagon in while loading cuttings or mud. Pressure washed in cellar/sub base.;Disinfect throughout the rig, handrails all equipment controls and crew van, inspect and PM crown, fuel camp and changeshack gens, fuel loader and disinfect cab and ladder. 8/4/2021 Disinfected change shack and crew van then sent night crew home early to minimize exposure to new crew coming on at noon, received surface centralizers, loaded rig mats and shipped to CCI yard, loaded two additional empty trailers with rig mats for shipping later. Tool Push did walk through with;fresh crew, reviewed things to do list.;Reviewed rig acceptance checklist, checked crown saver, CO rod wash alarm sensor pump #1, staged DP bunk in yard, set long pipe racks at catwalk, racked and strapped 86 jnts 4 1/2" drill pipe and 17 jnts HWDP. MU choke shock hose on rig floor, MU gas buster inlet hose from choke manifold.;Removed surface casing protectors and strapped same, troubleshot and resolved Pason wireless channel issue. Completed rig acceptance checklist. With test plug in wellhead filled stack with water to check for leaks, knife valve leaked, tightened that up, vac'd out stack,;PU 4 1/2" joint and set in annular, function tested diverter again to check knife valve, 3 second open time, LD jnt DP. CCI transported bed truck to Nikiski yard. Installed mast hyd cylinder covers. 18 n (LAT/LONG): evation (RKB): 50-231-20079-00-00API #: Well Name: Field: County/State: Whiskey Gulch 1 Whiskey Gulch Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: HEC 169 Job Name:211-00056.04 Whiskey Gulch 1 Drilling Spud Date: 8/5/2021 On covid stand-down, Made and installed splash skirt under rotary table for flow riser, trimmed and cleaned up liner and felt around rig foot print, installed secondary weight indicator on offside of derrick, mounted Quadco horn and light cluster in cellar area of sub, cleared spot on drillers side;of catwalk for cement silo and compressor, layed out Sperry tools and Yellow Jacket jars for DD selection, held teleconference spud meeting for Whiskey Gulch #1. CCI cleared a spot on location to stage cement bulk truck.;Scrub and clean lube room, load CCI trailer with plywood, valves and felt roll for return to town. 8/6/2021 Sorted through screens in screen connex, organize same, re-located Geronimo anchor block to clear path for cement trucks parking later, received cement silo and compressor, set silo and offloaded one bulk trailer into it, staged second bulk truck/trailer on pad, total surface lead cement;delivered = 300 sacks. Shipped out one trailer of rig mats to CCI yard and one trailer assorted items, work on PM’s, cont cleaning, organizing and sanitizing throughout the rig.;Change oil filters on compressor #2, installed latch on V door gate, organized sub rack, cont PM's and work orders, clean koomey room. 8/7/2021 Cleaned and organized drilling connex and spill connex, fueled portable gens, Weatherford power pack and Halliburton compressor, organized pushers dock, transferred all residual water from pits into pit 9, cleaned and sanitized mechanics truck, shipped two trailer loads rig mats to Swanson River;Tyler pad for staging. Sent AOGCC notice for upcoming diverter function test Monday afternoon, notified all service reps to get covid tested and prep to possibly spud Monday evening.;Scrubbed roof tops of pits, PM'd gen #2 and changed oil filters, set the 14" ID wear ring and removed run tool, scrubbed pit walls between pit mods, PM'd traveling blocks, primed various items for paint. Inspected magnaloy coupling on rig's HPU, staged rotary mousehole for PU DP, removed gen 1 and 2;radiator guards and cleaned radiators. 8/8/2021 Double checked equalizer line connections between pit mods, prep pits 1 through 7 to accept spud mud, removed box protectors from DP on racks in prep to PU rack back, offloaded 170 bbls spud mud into pits from G&I, set mousehole in rotary table, PU 86 singles, racked back 43 stands 4 1/2" DP.;Set short mousehole, offloaded remaining 173 bbls of spud mud into active, racked and strapped 17 jnts HWDP, PU racked back 8 stands HWDP, jar stand and NM Flex DC's, staged bit on rig floor.;Hauled 0 bbls of solids to KGF G&I Cumulative: 0 bbls Hauled 0 bbls of fluid to KGF G&I Cumulative: 0 bbls Hauled 0 bbls of cement G&I Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/9/2021 Got Quadco Rep and Mud Engineer covid tested and to the rig along with GeoLog. Quadco re-located one set of lights and horn to outer edge of pit 3 then tested all audio/visual gas alarms with no issues. GeoLog RU gas trap and umbilical, then started troubleshooting comm's in their unit.;Rig crew performed diverter function test with 4 1/2" jnt and took measurements of vent line and nearest ignition source, then performed drawdown test. Functioned flow and PVT alarms. Witness of diverter test waived by AOGCC Jim Regg at 09:58 on 8-9-21.;Filled hole with 24 bbls spud mud and had no leaks, PU johnny whacker, RIH and tagged at 135’ RKB while dusting spud MW up to 9.0 ppg. LD johnny whacker and single jnt, CCI troubleshot hurricane vac and got that running. Staged BHA components at catwalk.;PU motor w/1.5° bend, MU 13 1/2" HDBS tricone bit jetted w/4 x 16's, MU DM collar and scribed with an RFO of 126.98°, MU DGR,EWR, PWD, HCIM, ALD, CTN, HOC collars, XO's and topdrive. Plugged in and downloaded MWD, lined up and shallow pulse tested tools, held PJSM and loaded sources. MU stnd HWDP.;MU topdrive, started pumping at 460 gpm-742 psi, 42 rpm-2673 ft/lbs on bottom torque, drilled from 135' to 248', wob 12K, 100 ft/hr ROP. At 135' increased pump rate to 500 gpm- 960 psi, 128 ft/hr ROP, MW 9.2/vis 216, ECD's at 9.4 ppg, BGG 1 units. CBU at 248'. P/U-36K S/O- 37K ROT-35K;POOH w/ 2 stds. of HWDP for first BHA stage, and RIH w/ flex collars. No issues w/ trip or fill on bottom.;Cont. drilling 13.5" hole F/248'-T/400' GPM-500 SPP-1000 psi Diff-140 psi RPM-60 TQ-3K WOB-14 Max gas 10 units ECD-9.6 ppg P/U-36K S/O-37K ROT-35K.;Crew change. Cont. drilling 13.5" hole F/400'-T/430' GPM-505 SPP-1050 psi Diff-150 psi RPM-62 TQ-3.5K WOB-16.5 Max gas 10 units ECD-9.63 ppg P/U-39K S/O-42K ROT-42K.;POOH w/ 2 stds. of HWDP for second BHA stage, and RIH w/ jar std. and std. #5. No issues w/ trip or fill on bottom.;Resumed drilling 13.5" hole F/430'-T/654' GPM-508 SPP-1186 psi Diff-130 psi RPM-61 TQ-3.1K WOB-16K Max gas 26 units ECD-9.45 ppg P/U-39K S/O-41K ROT-40K. Started mixing 1st new batch of 6% KCL PHPA mud. Distance to well plan: 1.56' 1.53' High .32' Left.;Hauled 40 bbls of solids to KGF G&I Cumulative: 40 bbls Hauled 10 bbls of fluid to KGF G&I Cumulative: 10 bbls Hauled 0 bbls of cement G&I Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/10/2021 Cont directional drilling 13 1/2" surface hole from 654’ to 864'. Rot wob 15K, 506 gpm-1212 psi, 64 rpm-3400 ft/lbs on bott torque, 64 ft/hr ROP. Sliding wob 14K, 559 gpm-1390 psi, 107 psi diff, 5-30 ft/hr ROP. MW 9.2/vis 212, ECD's at 9.6 ppg, BGG 7 units, max gas 24 units, Started build at 803'.;Cont drilling from 864' to 987'. Sliding wob 16K, 557 gpm-1356 psi, 90 psi diff, 28 ft/hr ROP. Rot wob 16K, 555 gpm-1478 psi, 57 rpm-4482 ft/lbs on bott torque, 45 ft/hr ROP, MW 9.2/vis 242, ECD's at 9.5 ppg, BGG 17 units, max gas 39 units. Mad passed slide intervals, building at 3°/100'.;CBU twice at 550 gpm-1350 psi, 60 rpm-3600 ft/lbs off bott torque, obtained survey and flow checked. Well static.;Pulled up hole on elevators from 987' to 309' with no issue. Up wt 55K.;Serviced rig and topdrive, greased crown, blocks, draw works and brake linkage. Cleaned suction screens on mud pumps.;TIH on elevators from 309' to 927', MU topdrive, filled pipe, washed to bottom at 987' while starting a 20 bbl nut plug condet sweep around.;Cont. directional drilling 13.5" surface hole building at 3° per/100' F/927- T/1174'. P/U-56K S/O-58K ROT-57K GPM-550 SPP-1550 psi Diff-100 psi RPM-70 TQ-5.2K WOB-20K max gas 30 units ECD-9.6 ppg. Finished 1st batch of new 6% KCL PHPA mud.;Crew change, held PTSM outside. Cont. directional drilling 13.5" hole, building at 3° per/100' F/1174' to current depth of1397'. P/U- 58K S/O-58K ROT-58K GPM-555 SPP-1524 psi Diff-93 psi RPM-74 TQ-5.2K WOB-20K max gas 46 units ECD-9.63 ppg. Distance to well plan:11.96' 11.96' High 2.67' Right.;Hauled 180 bbls of solids to KGF G&I Cumulative: 220 bbls Hauled 330 bbls of fluid to KGF G&I Cumulative: 340 bbls Hauled 0 bbls of cement G&I Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs gp ;Rig crew performedgggp ggp diverter function test with 4 1/2" jnt and took measurements of vent line and nearest ignition source, then performed drawdown test. Functioned flow and PVT j alarms. Witness of diverter test waived by AOGCC Jim Regg at 09:58 on 8-9-21. p drilled from 135' to 248', directional drilling 13 1/2" surface hole from 654’ to 864' 8/11/2021 Cont directional drilling 13 1/2" surface hole from 1397' to TD at 1510' md/1488' tvd. Rot wob 20K, 556 gpm-1496 psi, 70 rpm-5239 ft/lbs on bott torque, 30-40 ft/hr ROP, MW 9.3/vis 212, ECD's at 9.6 ppg, BGG 15 units, max gas 40 units. At TD we are 20.57' high 4.40' right of the line in silty shale.;After obtaining survey, CBU 4 times to reduce mud viscosity from 212 to 78 and clean hole at 555 gpm-1372 psi, 73 rpm-4124 ft/lbs off bott torque. Filled trip tank, shut down and flow check = static. Gave AOGCC notice for upcoming casing run and cementing.;Pulled up hole on elevators from 1510' to 338' with no issue. Had a 12K overpull at 1043' (BHA pulling into a slide, no coal).;TIH on elevators from 338' to 1510' washing last stand to bottom after filling pipe. No issues TIH. Up wt 61K, dwn wt 60K.;Pumped a 20 bbl hi-vis nutplug sweep around at 555 gpm-1429 psi, 74 rpm-4000 ft/lbs off bott torque. Sweep came back 10 bbls early and we had a 50% increase in cuttings, had a max of 39 units at bottoms up, cont to circ until shakers cleaned up. Shut down and flow check = static.;Gave Halliburton e-line 4 hr notice, POOH on elevators from 1510' to BHA at 743', racked back HWDP, jars and NM DC's. Held PJSM and removed sources, plugged in and uploaded MWD data. LD Sperry smart iron, drained motor and LD same. RR bit graded a 1-1 and in gauge.;Clean and clear rig floor while spotting Halliburton e-line unit.;R/U HES E-line unit and tool, RIH to bottom E-line tools w/ no issues, logged OOH w/ E-line tools- GTET, Wave sonic, JLatch, and cabbage head.;P/U & M/U 13.5" cleanout assy. BHA #2 as per Sperry. RIH F/Surface-T/1510', M/U TDS, broke circ. washed last std. to bottom. Had no issues during trip and no fill on bottom. Had calculated pipe displacement. P/U-50K S/O-49K;Pumped 20 bbl Hi-Vis sweep w/ walnut & condet, sweep came back on time w/ a 20% increase in cuttings. Cont. circ. till shakers cleaned up. GPM-550 SPP-1075 psi RPM-70 TQ-4K Gave Weatherford casing hands 3 hr. notice.;Flow checked well (Static). L/D E-Kelley;Held PTSM outside on pad, crew change. Cont. POOH F/1485'-T/Surface, racked back HWDP, jars, & flex collars. Broke out bit, bit sub, & XO. Had no issues during tip out and had correct hole for the trip.;Drained stack, P/U test jt. & wear ring removing tool, pulled wear ring. Cleaned rig floor, changed out elevators, dummy run hanger & marked landing jt. L/D same. Gave HES cmt 4 hr. notice.;Held PJSM w/ rig crew, Weatherford, and DSM. R/U Weatherford casing equip. and loaded 10-3/4" shoe track & casing onto catwalk.;M/U and Baker locked shoe track, tested floats (ok),.Cont. RIH w/ 10-3/4" DWC/C L-80 45.5 ppf surface casing as per run tally F/127' to current depth 242'. Gave well hand 2 hr. notice.;Hauled 141 bbls of solids to KGF G&I Cumulative: 361 bbls Hauled 297 bbls of fluid to KGF G&I Cumulative: 619 bbls Hauled 0 bbls of cement G&I Cumulative: 0 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/12/2021 Cont PU single in hole with 10 3/4" surface casing from 242' to 1471'. top off string with fill up hose and MU landing joint/hanger. Slacked off and landed hanger, string went to bottom with no issues. Up wt 75K, down wt 63K. Topped off landing joint then RD fill up hose.;MU circ swedge and topdrive, PU 1' off seat and break circ at 137 gpm- 0 psi, RD Weatherford. Staged up to 5 bpm-0 psi, brought plug launcher to rig floor and loaded plugs. Shut down pump, broke off topdrive, MU plug launcher and plumbing to pump truck. Cont circ at 5 bpm-409 psi.;Held PJSM with rig team and cementers, Halliburton loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested lines at 804 low 3500 high, good tests. Halliburton pumped 75 bbls 10.5 ppg Tuned Prime Spacer at 5 bpm-119 to 81 psi, dropped bottom plug and pumped 130 bbls (300 sx);12 ppg Type II lead cement at 4.5 bpm-81 to 120 psi, followed by 74 bbls (360 sx) 15.8 ppg Type II tail cement at 4 bpm-129 psi. Started to overboard Spacer 22 bbls into tail cement. Halliburton dropped top plug, then displaced with 9.4 ppg Spud Mud at 5 bpm 126 to 520 psi. Slowed pump to 2 bpm with;10 bbl to go. Bumped the plug 135 bbls into displacement (calculated 136 bbls). Held 1340 psi (FCP of 540 psi) for 3 minutes, bled off and floats held. Bled back 1 bbl to truck. Had 75 bbls of Spacer returns to surface and 94 bbls lead cement to surface. Added Bridge Maker LCM to lead cement at 2.4;ppsx. Mix water temp 60 deg. Pumped 100% excess on both lead and tail. Lost 0 bbls throughout the job. Did reciprocate string until 39 bbls into displacement, seeing cement at shakers and landed the string. CIP at 14:33, 8/12/21. Washed up, RD and released Halliburton.;Backed out landing joint, pulled it to rig floor and flushed it out. LD landing joint, swapped to 4 1/2" elevators, PU kelly joint and XO, MU packoff run tool and packoff, RIH landed packoff, Wellhead Rep RILD's, POOH LD run tool. Start 4 bolting diverter vent line.;PU johnny wacker and MU on kelly joint. MU topdrive and pumped black water while rotating to flush annular, diverter T and spacer spool. Functioned annular a couple times and re-flushed. Shut down, broke down and LD johnny whacker and kelly joint.;ND diverter vent line, flow line, flow riser, knife valve, RU and removed annular, diverter T , spacer spool, and DSA.;N/U B section on well head, Tested FS seals 250 psi Low 5 min & 3000 psi High 15 min (ok);Staged BOP stack in cradle by catwalk, spotted CCI crane and laid over beaver side, pick and tailed in BOP into cellar area w/ crane, R/D CCI crane. Picked and set BOP's on B section w/ cellar hoists. Started mixing second batch of new 6% KCL PHPA mud and cont. to clean pits 1-3.;Held PTSM outside on pad, crew change. Cont. N/U BOP's, TQ BOP flange to well head, N/U choke & kill lines, removed trolley beams and hung catch pan, installed bell nipple and riser on annular, centered and chained off stack. M/U HYD BOP control lines to BOP. Removed 4" valves on conductor and;Capped. installed flow line to catch pan. Finished cleaning pits 1-3 and cont. working on building 2nd batch of new mud.;Changed out grabber box dies, M/U test jt. to test plug, set test plug, tested BOP controls, M/U TIW & dart valve to test jt. Flooded stack, choke manifold, and test equip. Functioned all valves & rams to purge out air.;Performed shell test 250 psi low and 3500 psi High (ok). Attempted to HYD IBOP w/ no luck, Changing out HYD IBOP at report time.;Hauled 89 bbls of solids to KGF G&I Cumulative: 450 bbls Hauled 402 bbls of fluid to KGF G&I Cumulative: 1021 bbls Hauled 94 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs RIH w/ 10-3/4"gqp g DWC/C L-80 45.5 ppf surface casing as per run tally F/127' to current depth 242' Didg reciprocate string until 39 bbls into displacement, Cont directional drilling 13 1/2" surface hole from 1397' to TD at 1510' md/1488' tvd. pggppppg p ropped bottom plug and pumped 130 bbls (300 sx);12 ppg Type II lead cement at 4.5 bpm-81 to 120 psi, followed by 74 bbls (360 sx) pppppg 15.8 ppg Type II tail cement at 4 bpm-129 psi. Lost 0 bbls throughout the job. )p Had 75 bbls of Spacer returns to surface and 94 bbls lead cement to surface. Cont PU single in hole with 10 3/4" surface casing from 242' to 1471'. pp p p gp Bumped the plug 135 bbls into displacement (calculated 136 bbls)ppg p () Pumped 100% excess on both lead and tail. p 8/13/2021 Removed test sub from saver sub, removed clamp and broke out saver sub, removed top clamp and changed out IBOP on topdrive quill shaft. Installed clamps, saver sub and test sub. RU test hose and tested both manual and hydraulic IBOP at 250/3500 with no issue. RD test equipment. Staged 100 jnts;4 1/2" DP on racks and tallied same for PU rack back prior to BOP test.;Pulled test plug with test joint to install wear ring, test plug hung up in annular element. Functioned element numerous times but bag would not relax to full open. Did pull test plug out but could not get wear ring down through element. Removed koomey line from closing side of annular, no change.;Re-scheduled BOP test time with AOGCC and Quadco Reps from to 18:00. Received 1 truckload 7 5/8" casing.;Removed flow line, flow riser and drip pan. Unbolted annular cap, RU and transferred to ground level, removed annular element from bowl. Had some protruding rubber between metal blocks on outer bottom edge of element, no significant damage. Cleaned and inspected bowl. No significant cuttings or;rubber debris found. Also inspected all three shakers for cracks or deck rubber wear, received 2nd load of 7 5/8" casing, total 66 jnts. Loaded empty trailers with items to be shipped, shipped out Weatherford equipment. CO valve on hopper #3. Greased and installed new annular element, RU and;installed annular cap, bolted down same. Inserted test jnt and function tested numerous times. Installed drip pan, flow riser and flow line. Chained off stack 4 ways, cleaned up tools etc. Installed test plug, flooded surface lines and stack, functioned valves and rams, purged air. Shell tested at;250/3500, good test. Quadco and AOGCC Reps on location at 18:00 hrs.;Quadco Rep tested all audio/visual gas alarms with no issue and released. Tested BOPE at 250/3500 psi for 5 min each on 4 1/2" test joint. Completed test #1, moved onto test #2, couldn't get a low test. Started trouble shooting and looking for leaks, pulled test plug and changed out dove tail seal;on test plug (had minimal wear). Reinstall test plug, functioned rams multiple time, re-purged out air. Attempted to test against lower rams only and still couldn't get a test. Re-hammered up studs on B section, found small leak on hose manifold valve off test jt. Replaced valve.;Re-tested against lower ram, had good test on low & high, attempted to test against upper rams (low test) noticed fluid leaking by rams down stack. Made decision to open ram cavities and inspect VBR's and door seal.;Held PTSM, crew change. Opened ram cavities, inspected VBR's (ok), Driller coming on tour mentioned they had an issue in the past with rams not closing equally and having more stem showing on one side then the other due to stack not being centered.;Buttoned up rams cavities, functioned upper & lower rams multiple times, seen were upper rams were not closing equally but 3/4" of an inch, re-centered stack with chain binders. Upper rams started closing properly. Proceeded to restart test w/ Test #1. Currently working on test # 7 out of 10.;Hauled 13 bbls of solids to KGF G&I Cumulative: 463 bbls Hauled 157 bbls of fluid to KGF G&I Cumulative: 1178 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/14/2021 Cont testing BOPE at 250/3500 psi for 5 min each and performed draw down test. Had to replace cord on Pason flow paddle.;Drained stack and removed test plug, re-flooded stack and choke manifold, functioned rams to remove air from ram cavities, opened valve on conductor 4" outlet. closed kill HCR.;Using test pump, at low speed, pumped 64.4 gallons to pressure up 10 3/4" surface casing tracking every inch of volume vs pressure to 3000 psi and held 30 minutes on chart. Good test. Bled back 64.4 gallons in 5 gallon buckets.;RD test equipment, installed 10" ID "long" wear ring, turned elevators, lined up CMV's and stack for drilling, closed valve on 4" conductor outlet, closed annulus valves. Loosened 4 way chains on stack, shimmed and leveled up sub/mast, tightened chains on stack.;MU 4 1/2" mule shoe on kelly joint, PU singled in hole 100 jnts DP in 1200' batches and racked back total 50 stands. Staged 22 jnts DP to single in BHA with.;PU Sperry motor w/1.5° bend, MU 9 7/8" HDBS 5 blade PDC bit jetted w/5 x 16's, MU DM collar and IBS, scribed with an RFO of 12.82°. MU DGR, PWD, ADR, ALD CTN and HOC collars. Plugged in and downloaded MWD, shallow pulse tested tools, held PJSM and loaded sources.;P/U and singled in the hole w/ 4.5" DP/BHA #3 F/747'-T/1400'. Had calculated pipe displacement. P/U-51K S/O-50K.;M/U TDS, broke circ. CBU, had soft cmt at 1405', drilled up cmt plugs in correct order, cont. drilling shoe track and 20' of new hole T/1530'. GPM-515 SPP-1730 psi Diff-150 psi RPM-40 TQ-5.5 ECD-9.3 ppg Max gas 15 units. P/U- 59K S/O-53K ROT-57K;Held PTSM and weekly safety meeting, crew change. CBU, Held PJSM on displacing over to 6% KCL PHPA mud. Lined up to and pumped 20 bbl Hi-Vis spacer, followed by 9.0 ppg new 6% KCL PHPA mud. Circ. and conditioned mud for LOT.;Shut down pumps, pulled into shoe, R/U testing equip. Performed LOT to EMW of 14.8 ppg 448 psi. Cont. pumping until 932 psi were leak off was seen. Pumped in .54 bbls and bled back .357 bbls, EMW of 21 ppg. R/D testing equip. Blew down choke manifold and re-lined up.;RIH to bottom. Cont. directional drilling 9-7/8" intermediate hole F/1530'-T/1714', building 3° per/100' to 1975'. GPM-518 SPP-1182 psi Diff-103 psi RPM-60 TQ-5K ECD-9.3 ppg Max gas 22 units. P/U-63K S/O-57K ROT-60K Distance to well plan- 21.88' 21.43' High 4.41' Right;Hauled 3 bbls of solids to KGF G&I Cumulative: 466 bbls Hauled 62 bbls of fluid to KGF G&I Cumulative: 1240 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/15/2021 Cont drilling the 9 7/8” intermediate section from 1714’ to 2114', rot wob 7K, 518 gpm-1131 psi, 60 rpm-4300 ft/lbs on bott torque, 150 ft/hr ROP. Sliding wob 9K, 563 gpm-1488 psi, 147 psi diff, 117 ft/hr ROP. MW 9.0/vis 56, ECD’s at 9.3 ppg, BGG 6 units, max gas 390 units in a sand at 2108’.;Cont drifting 7 5/8” casing and received 534 sx lead cement (more coming tomorrow).;Cont drilling from 2114', to 2545', rot wob 7K, 557 gpm-1621 psi, 80 rpm-7100 ft/lbs on bott torque, 150 ft/hr ROP. Sliding wob 5K, 555 gpm-1535 psi, 182 psi diff, 136 ft/hr ROP. MW 9.0/vis 50, ECD’s at 9.4 ppg, BGG 14 units, max gas 106 units.;CBU twice at 556 gpm-1488 psi, 75 rpm-5600 ft/lbs off bott torque. Obtained survey and SPR's, flow check = static.;Pulled up hole on elevators 17 stands from 2545' to 1490', up wt 78K, dwn wt 64K. Saw 20K overpull at 1720', worked through it again and was clean. Had calculated fill for the trip.;Serviced rig and topdrive, monitored well on trip tank, no loss, no gain.;TIH on elevators from 1490' to 2545' filling pipe and washing last stand to bottom with no issues or fill on bottom. Had calculated pipe displacement for the trip;Pumped a 20 bbl hi-vis nut plug sweep, half way into getting BU had to slow pumps down to 274 GPM due to super fines in the mud and shaker over running. Sweep came back 23 bbls late, probably due to turning down pumps (cuttings slip) . Had a 25% increase in cuttings.;Resumed directional drilling 9-7/8" intermediate section F/2545'-T/2865'. GPM-550 SPP-1600 psi Diff-100 psi RPM-80 TQ-6.7K WOB-8K Max gas 268 units ECD-9.5 ppg P/U-82K S/O-64K ROT-73K;Held PTSM, crew change. Cont. directional drilling 9-7/8" intermediate section F/2545'-T/3102'. GPM-555 SPP- 1675 psi Diff-200 psi RPM-80 TQ-7K WOB-6-8K Max gas 64 units ECD-9.5 ppg P/U-87K S/O-67K ROT-75K;Cont. directional drilling 9-7/8" intermediate section F/3102'-T/3163'. Pumped 20 bbl Hi-Vis w/ walnut. Resumed drilling ahead while pumping sweep around. Sweep came back 11 bbls early, w/ a 25% increase in cuttings.;Lost swab in MP #1, shut down pump and changed out swab while circ. w/ MP #2 and working pipe.;Resumed drilling ahead F/3272' to current depth of 3268'. GPM-555 SPP-1730 psi Diff-70 psi RPM-80 TQ-7K WOB-6-8K Max gas 36 units ECD-9.59 ppg P/U-88K S/O-67K ROT-75K Distance to well plan: 9.06' 4.46' High 7.88' Right.;Hauled 143 bbls of solids to KGF G&I Cumulative: 609 bbls Hauled 442 bbls of fluid to KGF G&I Cumulative: 1,682 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs ;Using testpgpg pump, at low speed, pumped 64.4 gallons to pressure up 10 3/4" surface casing tracking every inch of volume vs pressure to 3000 psi and held 30 minutes onpp p chart. Good test. p Cont. directional drilling 9-7/8" intermediate hole F/1530'-T/1714', g p Tested BOPE at 250/3500 psi for 5 min each on 4 1/2" test joint. Cont drilling the 9 7/8” intermediate section from 1714’ to 2114', g mud. g drilled up cmt plugs inpp p correct order, cont. drilling shoe track and 20' of new hole T/1530'. pp Cont. directional drilling 9-7/8" intermediate section F/2545'-T/3102'. p y ppg Performed LOT to EMW of 14.8 ppg 448 psi. Cont. pumping until 932 psi were leak off was seen. yy g followed by 9.0 ppg new 6% KCL PHPA my ppg EMW of qp 21 ppg. pppg ;Re-scheduled BOP test time with AOGCC a 8/16/2021 Cont drilling the 9 7/8" intermediate section from 3268' to 3535', rot wob 6K, 55 gpm-1843 psi, 80 rpm-7744 ft/lbs on bott torque, 129 ft/hr ROP. MW 9.1/vis 58, ECD's at 9.5 ppg, BGG 13 units, max gas 81 units. Received another 266 sacks lead cement, staged 22 jnts DP for PU.;CBU twice at 556 gpm-1659 psi, 80 rpm- 6936 ft/lbs off bott torque. Obtained survey, SPR's and flow checked (static).;Pulled up hole from 3535' to 2540', up wt 99K. Pulled 20k over or tight spots at 3176'-3123'-2990'-2959'-2929'-2875'-2766'. Had to MU topdrive and backream at 2632' as it would not clean up on elevators.;At 2540' MU topdrive and CBU at 563 gpm-1580 psi, 80 rpm-6200 ft/lbs off bott torque. At bottoms up had 10% increase in fine heavy cuttings, once shakers cleaned up shut down for rig service. Serviced rig and topdrive.;PU singled in hole with 22 jnts 4 1/2" DP from 2547' to 3351', down wt 63K, then ran in 2 stands to 3477'. MU last stand and topdrive, filled pipe and washed down with +/- 4' of fill.;CBU followed with a 20 bbl hi-vis nutplug sweep at 552 gpm-1605 psi, 80 rpm-6275 ft/lbs off bott torque. Had 25% increase in fine heavy cuttings at bottoms up, 10% with sweep to surface.;Resumed drilling 9 7/8" hole from 3535' to 3841', rot wob 7K, 555 gpm-1934 psi, 80 rpm-7519 ft/lbs on bott torque, 140 ft/hr ROP, MW 9.2/vis 65, BGG 13 units, max gas 110 units.;Cont. directional drilling 9-7/8" intermediate section F/3841'-T/ 4279', Pumped 20 bbl Hi-Vis sweep @ 4030', sweep came back 84 bbls early w/ a 20% increase in cutting. GPM-550 SPP-1950 psi Diff-200 psi RPM-80 TQ- 8.6K WOB-8K Max gas 103 units ECD-9.65 ppg P/U-109K S/O-78K ROT-91K;Held PTSM, crew change. Cont. directional drilling 9-7/8" intermediate section F/4279'-T/ 4587'. GPM-550 SPP-2050 psi Diff-200 psi RPM-80 TQ-9K WOB-7-10K Max gas 103 units ECD-9.5 ppg P/U-116K S/O-80K ROT-96K;Circ. till shaker cleaned up. GPM-550 SPP-1825 psi RPM-80. Flow check (static), Got SPR's.;POOH on elevators F/4587' to current depth at report time 3644'. Distance to well plan: 10.77' 4.2' High 9.91' Right.;Hauled 181 bbls of solids to KGF G&I Cumulative: 790 bbls Hauled 424 bbls of fluid to KGF G&I Cumulative: 2,106 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/17/2021 Cont pulling up hole for wiper trip to shoe, from 3644’ to 1735’. Pulled 25 to 30K over at 3644'-3514'-2365'-2322'-2253'-2069'-2004'-1970' but able to work through on elevators and clean them up.;At 1735' MU topdrive and CBU with BHA outside surface shoe. 548 gpm-1465 psi, 80 rpm-5347 ft/lbs off bott torque. Shut down and pulled up into shoe parking at 1483'.;Shut down rig gen, Hilcorp Electrician changed out 3 electrical plugs and receptacles on topdrive HPU, fired up rig gen and serviced rig and topdrive.;TIH from 1483' to 2930' and set down 3 times. MU topdrive, filled pipe, washed and reamed down to 2973', worked stand with no pump/rotary and was clean. Cont TIH and had to work tight spot at 3424' on elevators, at 4461' had to MU topdrive, fill pipe and washed/reamed to bottom at 4587'.;CBU at 505 gpm-1762 psi, 80 rpm-9000 ft.lbs off bott torque. Put 20 bbls low vis low weight pill on vac truck, built 20 bbls hi vis hi weight pill in pill pit. At bottoms up hole unloaded heavy fine sand, 50% increase. Pumped tandem sweep around and had 10% increase to surface. 18 bbls early.;Made hook and resumed drilling intermediate from 4587' to 4776', rot wob 9-10K, 557 gpm-2000 psi, 80 rpm-10,000 ft/lbs on bott torque, 110 ft/hr ROP, MW 9.2/vis 57, BGG 23 units, max gas 74 units.;Cont drilling from 4776' to 5222'7-10k WOB, 559 gpm 2190 psi, 80 RPM, 9.8 - 11k torque on bottom. 74 ROP 9.2 ppg MW, 15 units BGG 212 Max Gas units;Cont Drilling from 5222' t/ 5575' 8-10k WOB 555 GPM 2250 psi 80 RPM 8-11k tq on 9.2 ppg MW 9.67 ppg ECD, Distance to plan 3.84' 3.78' high .068' right;Circulate bottoms up, shakers cleaned up after bottoms up, flow checked well static slight loss, obtain SPR's and survey;POOH f/ wiper trip f/ 5575' t/5161' hit tight spot Kelly up and work through with pumps;Hauled 158 bbls of solids to KGF G&I Cumulative: 948 bbls Hauled 452 bbls of fluid to KGF G&I Cumulative: 2,558 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/18/2021 Cont pulling wiper trip up hole from 5161' to 4586'. At 5162' pulled 35K over three times. MU topdrive and backreamed from 5194' up to 5134'. Upper BHA coming into a large coal sequence at 4920', bit coming out of a coal and into mudstone. Worked stand with no pump or rotary and it's clean.;Serviced rig and topdrive, crown, blocks, brake linkage and checked driveline bolts.;TIH on elevators from 4586' to 5524' and MU topdrive on last stand. No issues going in hole.;CBU at 553 gpm-2123 psi, 80 rpm-8200 ft/lbs off bott torque. Screens started blinding off well before bottoms up due to fine sand. Reduced pump rate to 360 gpm to keep mud on shakers. Had 50% increase in fine sand at bottoms up. Followed with a 20 bbl hi-vis nut plug sweep and able to increase pump;rate again. Sweep came back 35 bbls early and a 10% increase in cuttings. Made hook.;Cont drilling from 5575' to 5720', rot wob 9-10K, 555 gpm-2225 psi, 80 rpm- 10,000 ft/lbs on bott torque, 70 to 140 ft/hr ROP, sliding wob 8K, 554 gpm-2327 psi, 247 psi diff, 81 ft/hr ROP. MW 9.3/vis 60, ECD's at 9.6 ppg, BGG 7 units, max gas 104 units.;Cont drilling from 5720' to 6084', 544 gpm-2404 psi, 60 rpm-10,250 ft/lbs on bott torque, 70 to 100 ft/hr ROP, MW 9.3/vis 55, ECD's at 9.7 ppg, BGG 15 units, max gas 141 units.;Cont drilling from 6084' to 6340' 555GPM 2400 psi 60 RPM 10-12k tq on bottom Pump # 2 stopped stroking but engine was running, shut down pump and found Rim Pack coupler between engine and pump sheave was wore out;Circulate bottoms up on 1#1 pump, parts on the way from Kenai to fix pump;Make wiper trip f/ 6340' t/ 4460' worked through small over pulls, Pump back together;Service Rig and test mud pumps all checked out;RIH f/ 4460' t/ 6073' had one tight spot had to ream through @ 5764';Hauled 104 bbls of solids to KGF G&I Cumulative: 1052 bbls Hauled 311 bbls of fluid to KGF G&I Cumulative: 2,869 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs Cont drilling the 9 7/8" intermediate section from 3268' to 3535', ;Cont drilling from 4776' to 5222'7 gp p ;Cont drilling from 6084' to 6340' gp p ;Cont. directional drilling 9-7/8" intermediate section F/3841'-T/ p 4279', 8/19/2021 TIH on elevators from 6239' to 6319' and set down three times. MU topdrive, filled pipe, washed and reamed down to bottom at 6340' at 388 gpm-1503 psi, 80 rpm-11,000 ft/lbs off bott torque.;CBU at 338 gpm-1148 psi, staging up pump rate as shakers allowed to 552 gpm-2302 psi. At bottoms up had a 50% increase in fine heavy sand. Pumped a 20 bbl hi-vis nutplug sweep down drill string. Once sweep exited the bit resumed drilling.;Cont directional drilling 9 7/8" hole from 6340' to 6494'. Sliding wob 7K, 559 gpm-2564 psi, 228 psi diff, 45 ft/hr ROP. Rot wob 10K, 558 gpm-2548 psi, 70 rpm-11,900 ft/lbs on bott torque, 50 ft/hr ROP, MW 9.3/vis 63, ECD's at 9.7 ppg, BGG 20 units, max gas 51 units. Sweep back 28 bbls early, 10%;Cont directional drilling 9 7/8" hole from 6494' to 6635', rot wob 7K, 557 gpm-2467 psi, 63 rpm-8251 ft/lbs on bott torque, 60 ft/hr ROP. Sliding wob 4K, 556 gpm-2444 psi, 199 psi diff, 23 ft/hr ROP, MW 9.3/vis 59, ECD's at 9.6 ppg, BGG 10 units, max gas 92 units. Cont dropping inc toward 10-11°;Cont Drilling 9 7/8'' Hole f/ 6635' t/ 6780' 555 GPM 2400 psi 80 RPM 10-16k tq on bottom 9.35 ppg MW Continue dropping 3° - 100 slide drilling having issues with stacking weight rocking pipe back and forth to keep f/ stalling out and packing off;Cont Drilling 9 7/8'' hole f/ 6780' t/ 6940' 555 GPM 2425 psi 60 RPM 10-14k tq on bottom 9.35 ppg MW Slide drilling dropping angle 3° - 100' t/ 11° Slide drilling still stacking weight rocking pipe Distance to Plan 7.47' 7.44' Low .71' Right;Hauled 94 bbls of solids to KGF G&I Cumulative: 1146 bbls Hauled 316 bbls of fluid to KGF G&I Cumulative: 3,185 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/20/2021 Cont drilling 9 7/8" hole from 6940' to 7127'. Rot wob 10K, 553 gpm-2525 psi, 60 rpm-10,850 ft/lbs on bott torque, 50 to 60 ft/hr ROP, MW 9.3/vis 54, ECD's at 9.6 ppg, BGG 15 units, max gas 111 units.;CBU at 555 gpm-2369 psi, 60 rpm-10,264 ft/lbs off bott torque.;Backreamed up the hole from 7127' to 6254' at 548 gpm-2247 psi, 60 rpm-10,600 ft/lbs off bott torque, up wt 178K coming off bottom. No issues reaming through entire drop section. Lined up on low side and shut down pumps, parked string at 6317'.;Serviced rig and topdrive, cleaned mud pump suction screens, installed new cotter key in torque tube turnbuckle pin.;TIH on elevators from 6317' to 7067' with no issue, MU topdrive on last stand, filled pipe, washed/reamed to bottom at 7127'.;CBU at 555 gpm-2389 psi, 60 rpm- 10,394 ft/lbs off bott torque. Didn't have to reduce pump rate any lower than 500 gpm-1965 psi. No significant increase in cuttings. Once shakers could handle 55 gpm made hook to resume drilling ahead.;Cont drilling from 7127' to 7276', rot wob 11K, 557 gpm-2483 psi, 60 rpm-10,972 ft/lbs on bott torque, 73 ft/hr ROP, MW 9.4/vis 56, ECD's at 9.7 ppg, BGG 6, max gas 96 units. Received centralizers.;Cont drilling from 7276' to 7599' 555 gpm 2440 psi 60 rpm 10-14k tq on bottom MW 9.35 ppg ECD 9.66 65 -80 ROP avg;Cont drilling from 7599' t/ 7710' 555 gpm 2580 psi 60 rpm 10-12k tq on bottom 9.4 ppg MW 9.79 ppg ECD MWD failure lost gamma, Perform mode switch no change re attempt lost direction Discuss options with town engineer decision made to pull, Distance f/ plan 24.02' Low .01 Right;CBU obtain sample for mud logger, Flow check well, slight loss, Obtain SPR's;POOH on elevators f/ 7710' t/ 6045' work through tight spots w/ pump and rotary @ 6213' and 6104';Hauled 57 bbls of solids to KGF G&I Cumulative: 1203 bbls Hauled 188 bbls of fluid to KGF G&I Cumulative: 3,373 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/21/2021 Cont POOH on alternate breaks, due to DTF, from 6045’ to 5541'. Had to backream at 6040', 5986' and 5951'. At 5541' pulling good so stopped to level sub and derrick.;Unchained BOP stack in cellar, raised and shimmed under off-side sub base. Quadco Rep on location at 07:00 and tested all audio/visual gas alarms with no issues. Got notification we will call current depth of intermediate section TD (7710');Cont POOH on alternate breaks from 5541' to 1700'. Had to backream at 4238', 3675', 3175', 2261'. Stopped at 1700' with BHA outside surface shoe to CBU. CBU at 546 gpm-1530 psi, 20 rpm-3300 ft/lbs off bott torque. 10% increase in cuttings to surface.;Cont POOH to BHA at 747', racked back HWDP, jars and NM flex DC's. Held PJSM and removed sources, plugged in and uploaded MWD data. LD Sperry directional tools, drained motor and broke off bit. Bit graded at 1-2-WT-G-X-3-No-DTF;Clean and clear rig floor, drained BOP stack and rinsed same, PU 4 1/2" test joint and removed wear ring. Set test plug and RU test equipment.;Test BOPS w/ 4.5'' Test Jt t/ 250/ 3500 psi f/5 min each, State Inspectors Waived Witness, test upper lower and blind rams, annular, CMV 1-15, HCR and man choke and kill, TIW and Dart, Auto and Man IBOP, Mezz kill valve, Electric and Man super chokes, perform drawdown test, Quadco tested gas alarms;Had no fail passes;R/D test equipment, Blow down choke manifold, Pull test plug set wear ring.;P/U Clean out BHA as per Directional driller,;RIH t/ 1494' fill pipe, hole took correct displacement;Slip and cut drilling line;Continue RIH f/ 1494' t/ 6949' Set down 20k Unable to work down had to pump and ream through slide intervals @ 6237' & 6265' No other hole issues hole took correct displacement.;Hauled 31 bbls of solids to KGF G&I Cumulative: 1234 bbls Hauled 124 bbls of fluid to KGF G&I Cumulative: 3,797 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/22/2021 Cont TIH from 6949' to 7515' and set down three times. MU topdrive, filled pipe, washed and reamed down to 7566' at 469 gpm-1256 psi, 60 rpm-8500 to 9000 ft/lbs off bott torque. At 7566' set down again. Washed and reamed down to 7690', PU single, MU topdrive, washed/reamed down to 7710';CBU at 543 gpm- 1867 psi, 80 rpm-11,015 ft/lbs off bott torque, reciprocating string. Had 50% increase in cuttings at bottoms up. Pumped 20 bbl hi-vis nutplug sweep around at 613 gpm-2191 psi, 80 rpm. Sweep back 28 bbls late and 25% increase in cuttings. Shut down and flow checked = slight seepage.;POOH on elevators from 7710' to BHA at 632' with no issues. Racked back HWDP, jars and NMDC's, LD stab, XO, bit sub and bit as one component. Re-run bit graded a 1-2.;Cleaned up rig floor, spotted Halliburton e-line unit and staged their tools.;RU e-line equipment, MU Sonic/Imager tool string, start first RIH at 18:40. Set down at 5290' (10' coal), cont to work tool string, POOH reconfigure tools string, add stabilizers and hole finder nose, RIH 24:00 hrs set down same place 5290' Work tools unable to get down, Log out of the hole to shoe;Out of the hole @ 0500 hrs, Break down tool string components, prep to P/U side wall coring tool string.;Hauled 34 bbls of solids to KGF G&I Cumulative: 1268 bbls Hauled 128 bbls of fluid to KGF G&I Cumulative: 3,925 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs pp y ;Cont drilling from 7127' to 7276', pp q ;Cont directional drilling 9 7/8" hole from 6494' to 6635' Got notification we will call current depth of intermediate section TD (7710'); Cont drilling 9 7/8" hole from 6940' to 7127'. 8/23/2021 Halliburton e-line loaded software, PU and assembled SWC tool string, total length 74'. RIH to 5290' and set down numerous times, decision made to obtain core samples from 4570' up to 1690', total 19 stations.;E-line pulled up hole and obtained core samples at 4570', 4501', 3655', 3475', 3376', 3112', 2915', 2900', 2766', 2646', 2625', 2427', 2259', 2106', 2076', 2071', 2002', 1962' and 1690'. Pulled OOH, broke down /LD tool string, processed and packaged core samples, loaded tool basket, RD and released.;PU 9 7/8" cleanout assembly: RR3 HDBS PDC bit, bit sub, XO, stabilizer sub, RIH with NMDC's, HWDP and jars for a BHA length of 632'. Stopped at 2177' and filled pipe, cont RIH to 7710' Wash and ream through tight spots @ 5163' , 5282', 6194', 7452' Washed last stand to bottom.;CBU 10% increase in cuttings on bottoms up, Pump Hi Vis sweep around 611 gpm 2111 psi no increase in cuttings on sweep return 27 bbls late, flow check well static slight seepage;POOH on Elevators f/ 7710' t/ 647' Stand back and L/D BHA @ 197';Hauled 36 bbls of solids to KGF G&I Cumulative: 1304 bbls Hauled 144 bbls of fluid to KGF G&I Cumulative: 4,069 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/24/2021 L/D Jars and NMFC, Stab bit and bit sub, Give state notice f/ upcoming BOP test;Cleaned and clear floor, drained stack pulled wear ring set test plug, C/O upper rams t/ 7 5/8'' solid body, Flooded stack and surface lines.;Test Annular and upper rams w/ 7 5/8'' test jt t/ 250/3500 psi 5 min each good tests;R/D test equipment, removed test jt and test plug, dummy run landing jt and hanger (20.27') staged centralizers and circ swedge R/U fill up line R/U Weatherford.;PJSM, M/U shoe track and check floats, floats good, Continue P/U 7 5/8'' Casing as per detail t/ 1484' circulate pipe volume 277 gpm 101 psi, continue RIH w/ casing t/ 3848' Circulate pipe volume 250 gpm 184 psi Continue RIH w/ casing t/ 7695' tag fill, M/U circ swedge and wash down t/ 7701' land on;hanger, Stage rate t/ 6.6 bpm 256 psi;Circulate and condition mud f/ cement job;M/U cement head and break circulation with cementers, PJSM with all hands;Halliburton loaded lines with 5 bbls water and checked for leaks. Halliburton pressure tested lines at 364 low 4100 high, good tests. Halliburton pumped 40 bbls 10.5 ppg Tuned Prime Spacer at 4 bpm- 316 psi, dropped bottom plug and pumped 333bbls (800 sx) 12 ppg Type I II lead cement at 6 bpm- 254;to 125 psi, followed by 30 bbls (145 sx) 15.8 ppg Type I II tail cement at 4 bpm- 140 psi. Halliburton dropped top plug, then displaced with 9.4 ppg 6% KCL at 5 bpm 140 to 1240 psi. Slowed pump to 3 bpm with 10 bbl to go. Bumped the plug 345.5 bbls into displacement (calculated 349.6 bbls). Held 600;psi (FCP of 1240 psi) for 3 minutes, bled off and floats held. Bled back 2.75 bbl to truck. Started to overboard Spacer 335 bbls into displacing cement. Had 10 bbls of Spacer returns to surface and 0 bbls lead cement to surface. Mix water temp 65 deg. Pumped 40% excess on both lead and tail. Lost 0;bbls throughout the job. Did reciprocate string until swapped to displace and was sticky getting back to hanger CIP at 06:29, 8/25/21. Washed up, RD and released Halliburton.;Hauled 26 bbls of solids to KGF G&I Cumulative: 1330 bbls Hauled 234 bbls of fluid to KGF G&I Cumulative: 4,303 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/25/2021 Cement 7-5/8" casing - job notes on 08/25/2021 report. CIP at 06:29, 8/25/21. Wash up, rig down and release Halliburton cementers. Change out liners on mud pumps to 5";Lay down landing joint and wash top of hanger. Make up running tool and pack-off to joint of DP. Install pack-off and RILDS per Vault wellhead rep. Pressure test pack-off seals / hanger void to 5000 psi for 10 mins - good test.;Install test plug and change out upper rams from 7-5/8" to 2-7/8" x 5" VBRs. Rig down casing handling equipment and bail extensions. Make up test joint and floor valves for BOPE test.;Rig up BOPE test equipment. Flood stack and work out air. Function all choke manifold valves and fluid pack lines. Perform shell test - good test.;Test BOPE 250/3500 psi for 5/5 min each. Test notification sent to AOGCC on 05/24/2021 at 05:21. Test witness waived by Jim Regg on 05/24/2021 at 16:27. All tests with 4-1/2" test joint.;R/D test equipment, Blow down lines, Load BHA on catwalk and P/U Cross overs t/ floor;P/U Directional BHA as per DD/MWD, M/U bit, motor and MWD, Get offsets, Upload MWD and Shallow test string, Load Sources, P/U remaining BHA f/ rack, RIH w/ HWDP f/ Derrick t/ 740';Slip and cut drilling line 52', service rig and top drive.;RIH w/ Drilling BHA f/ 740' P/U 76 singles f/ pipe rack t/ 3093';Continue RIH f/ 3093' t/ 7545' out of the derrick;Circulate bottoms up 250 gpm 2015 psi;R/U and test 7 5/8'' Casing t/ 3500 psi f/ 30 min on chart, Pressure up w/ test plug 3.5 bbls pumped in 3.2 bbls returned, R/D test equipment;Wash and ream f/ 7545' t/ 7614' tag plugs, Drill plugs and float collar t/ 7616' Drill cement t/ 7699' Drilling on float shoe;Hauled 67 bbls of solids to KGF G&I Cumulative: 1397 bbls Hauled 783 bbls of fluid to KGF G&I Cumulative: 5,086 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/26/2021 Continue to drill out remainder of shoe and 20' of new hole F/ 7699' - T/ 7730' MD. 250 gpm, 2100 psi, 50 rpm, 12.5K tor, 5K WOB. 180K up, 95K dn, 125K rot,;Circulate hole clean and rig up to perform LOT. MW in/out = 9.5 ppg;Conduct LOT: 7-5/8" shoe at 7701' MD, 6801' TVD, 9.5 ppg MW in/out, Leak off pressure at 1320 psi - 13.2 ppg EMW. pumped 147 gallons, bled back 90 gallons. Sent LOT data to ODE and received ATP with drilling 6-3/4" Production hole section.;Rig down and blow down test equipment. Line up pits and pumps.;Service top drive and rig floor equipment;Drill 6-3/4" production hole section per DD F/ 7730' - T/ 8105' MD: 375' total, 57.7 fph AVROP, 286 gpm, 2348 psi, 20% RF, 50 rpm, 13-14K Tor, 5-8K WOB, MW in/out 9.2 ppg. ECD 10.9 ppg. 193K up, 100k dn, 134K rot.;Continue Drilling 6 3/4'' Production Section f/ 8105' t/ 8538' 290 gpm 2029 psi, 60 rpm 11-13k tq on, 5-8k WOB, MW 9.2 ppg 10.01 ppg ECD, 72.1 FPH Avg ROP;Continue Drilling 6 3/4'' Production Section f/ 8538' t/ 8913' 290 gpm 2404 psi, 60 rpm 11-14k tq on, 5-8k WOB, MW 9.2 ppg 10.26 ppg ECD, 62.5 FPH Avg ROP Distance to plan 61.07' 61.07' Low 7.54' Right;Hauled 8 bbls of solids to KGF G&I Cumulative: 1405 bbls Hauled 72 bbls of fluid to KGF G&I Cumulative: 5,158 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs g g ;E-line pulled up hole and obtained core samples pp Pumped 40% excess on both lead and tail. gp qp ;Test BOPE 250/3500 psi for 5/5 min each. gp 13.2 ppg EMW. Give state notice f/ upcoming BOP test; ggpp ;R/U and test 7 5/8'' Casing t/ 3500 psi f/ 30 min on chart, Pressure up w/ test plug 3.5 bbls pumped in 3.2 bbls returned, pggppppg opped bottom plug and pumped 333bbls (800 sx) 12 ppg Type I II lead cement at 6 bpm- 254;to 125 psi, followed by 30 bbls (145ppppp sx) 15.8 ppg Type I II tail cement at Continue to drill out remainder of shoe and 20' of new hole F/ 7699' - T/ 7730' ;Test Annular and upper rams w/ 7 5/8'' test jt t/ 250/3500 psi pg p( p) Had 10 bbls of Spacer returns to surface and 0 bbls lead cement to surface. M ;Conduct LOT: Halliburton dropped top plug, then displaced with 9.4 ppg 6% KCL p p ( ) ppg yp p p floats held. RIH w/ casing t/ 3848' C p Test notification sent to AOGCC on 05/24/2021 at 05:21. Test witness waived by Jim Regg on 05/24/2021 Leak off pressure at 1320 psi pp Bumped the plug 345.5 bbls into displacement (calculated 349.6 bbls). pp p p g p pgpp wash down t/ 7701' land on;hanger, g ;Continue Drilling 6 3/4'' Production Section f/ 8538' t/ 8913' change out upper rams from 7-5/8" to 2-7/8" x 5" VBRs. gg ;Drill 6-3/4" production hole section per DD F/ 7730' - T/ 8105' MD: gp Continue RIH w/ casing t/ 7695' tag fill, Drill cement t/ 7699' Drilling on float shoe; ppgpp g Lost 0;bbls throughout the job. 8/27/2021 Continue Drilling 6 3/4'' Production Section f/ 8913' t/ 9037' 290 gpm 2100 psi, 60 rpm 11-14k tq on, 5-8k WOB, MW 9.2+ ppg 12.28 ppg ECD, 82.7 FPH Avg ROP;Pump 9.2 ppg high-vis sweep with walnut at 9037' MD. Sweep back on time with 25% increase in cuttings. Take survey and SPRs on bottom.;Perform wiper trip back to 7-5/8" shoe on elevators. Pull f/ 9037' - t/ 7674' md. No hole issues while pulling.;Perform rig service before running back to bottom. Grease crown, blocks, top drive, drawworks, drive shaft, break linkage and iron roughneck. Pull and clean mud pump suction and discharge screens. Verify pulsation dampener pre-charge on both pumps (750 psi).;Wiper trip back to bottom on elevators. Run in f/ 7674' - t/ 9037' MD. Wash and ream last stand to bottom. 210k up, 105k dn, 142k rot, 290 gpm, 2159 psi, 60 rpm, 14k tq. No hole issues while running in. 6' of fill on bottom.;Drill Ahead f/ 9037' t/ 9470' 286 gpm 2157 psi, 65 RPM 14-16k tq on ,9.2 ppg 10.03 ppg ECD, 71.8 Avg ROP, 5-8K WOB;Drill Ahead f/ 9470' t/ 9777' 290 gpm 2508 psi, 60 rpm 13-16k tq on, 9.2 ppg 10.21 ppg ECD, 51.1 Avg ROP, 5-8k WOB;Drill Ahead f/ 9777' t/ 10028' 290 gpm 2450 psi 60 rpm 14-16k tq on, 9.2 ppg MW 10.22 ppg ECD, 41.8 Avg ROP, 5-8k WOB, Distance to Plan 70.48' 70.48' Low 1.46' Left;Hauled 62 bbls of solids to KGF G&I Cumulative: 1467 bbls Hauled 183 bbls of fluid to KGF G&I Cumulative: 5,341 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/28/2021 Drill Ahead 6 3/4'' Hole Section f/ 10,028' t/ 10,271' TD 290 gpm 2660 psi 60 rpm 14-16k tq on 9.2 ppg MW 10.25 ppg ECD, Distance from Plan 79.05' 77.36' Low 16.28' Right;Circulate bottoms up x 2;POOH f/ 10271' t/ 7675' No Hole issues, Hole took correct fill;Service rig and top drive;RIH f/ 7675' t/ 10271' No hole issues, Wash Last stand to bottom no Fill;Pump Hi Vis Sweep around sweep back on time 10% increase in cuttings, circulate shakers clean, Build and pump Dry Job;POOH f/ 10271' t/ 740';Stand Back BHA, Unload Sources, Download MWD, Clean and Clear Floor;Hauled 34 bbls of solids to KGF G&I Cumulative: 1501 bbls Hauled 51 bbls of fluid to KGF G&I Cumulative: 5,392 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/29/2021 Continue Downloading MWD, L/D BHA as per DD/MWD, Break Bit graded a 8-3 RO Clean and Clear floor;Service rig and trop drive;R/U Halliburton E Line M/U Slim Hole Caliper tool string RIH to bottom Log out of the hole to shoe, POOH, L/D Slim hole caliper string, M/U Sonic Dipole and imager tool string RIH t/ 10261' Tag up Log out of the hole to shoe, POOH L/D Tool String, P/U Side Wall Coring string RIH take 19 core samples;as per GEO, POOH, L/D Sidewall coring tool string, M/U CBL Tool String RIH t/ 7 5/8'' Shoe @ 7701' Log out of the hole, L/D Tool String, R/D Halliburton and release;Clean and Clear Rig Floor R/U to L/D HWDP and Flex Collars f/ derrick;Hauled 17 bbls of solids to KGF G&I Cumulative: 1518 bbls Hauled 158 bbls of fluid to KGF G&I Cumulative: 5,550 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/30/2021 L/D HWDP and Flex Collars from Derrick, clean and clear floor;R/U Weatherford Casing Equipment;M/U Mule Shoe RIH w/ 4.5'' IBTM Liner t/ 2727' M/U Disconnect and X Over;RIH w/ 4.5'' liner on DP f/ 2727' t/ 10261' Set down 10125' Washed remaining jts to bottom;Circulate and condition mud f/ cement job 253 gpm 903 psi, M/U side entry sub and pups;PJSM Cement as per detail, PT Lines 393 psi Low 4700 high, Mix and Pump 25 bbls of 10.5ppg tune prime spacer 4 bpm 120 psi, Pump 123 bbls 15.3ppg PTA Cement @ 5 BPM 75 PSI FCP, Drop Disconnect Dart, Pump 5 bbls 15.3 ppg PTA Cement followed by 15 bbls 10.5ppg Tune Prime Spacer Displace w/ 75 bbls of;Mud plug latched up pressured up t/ 2440 psi and released f/ Liner Shut down and allow to equalize, L/D Cement equipment, Wash up truck CIP 0100 hrs;POOH f/ 7539' t/ 6595' 120k PUW 75k SOW;Drop Wiper Balls and Circulate @ 524 gpm 1334 psi 40 RPM 10-15 bbls of contaminated mud on bottoms up;POOH f/ 6595' t/ 2250' Started L/D Pipe @2464' Vacuuming Wiper Balls through pipe and cleaning threads;Hauled 2 bbls of solids to KGF G&I Cumulative: 1520 bbls Hauled 248 bbls of fluid to KGF G&I Cumulative: 5,798 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs 8/31/2021 POOH L/D 4 1/2'' DP f/ 2250' to surface vacuuming Wiper Balls through pipe and cleaning threads. Clear and clean the rig floor 1.9 bbls over calculated displacement on TOOH;Service crown, blocks, top drive, draw works, brake linkage and drive shaft. Troubleshoot iron ruffneck pipe spinners, clamp operating slower than normal.;PJSM, R/U power tongs, 4 1/2'' handling equipment, ready FOSV and XO, M/U WLEG and RIH with 13 jts 4-1/2”, 12.6#, L-80, IBT kill string to 518', torque to 4000 ft/lbs, R/D power tongs and handling equipment/ R/U to run 4 1/2'' DP;PJSM with on coming crew, M/U XO, 1 jt 4 1/2'' DP, 7 5/8'' casing scraper and XOs to 568', TIH on stands of 4 1/2'' DP F/565'-T/7404', Tagged TOC at 7404', confirmed tag w/ 10K set down. Had calculate pipe displacement for the trip. Summitted 24 hr. BOP notice to AOGCC if need.;Circ. & conditioned mud x2 BU. GPM-550 SPP-1596 psi MW 9.25 ppg;R/U testing equip. Tested casing/abandonment plug T/1700 psi for 30 min on chart. Pumped in 1.86 bbls and bled back 1.86 bbls.;R/D testing equip. CBU while confirming test results w/ drilling engineer. GPM-377 SPP-909 psi MW 9.25 ppg;R/U testing equip. Re-tested casing/abandonment plug T/1700 psi for 30 min on chart due to discrepancies between volume pumped and pressures (Good test). Pumped in 1.78 bbls and bled back 1.78 bbls. Blow down choke, flushed test pump.;Held PJSM on displacing well over to 6% KCL brine w/ rig crew, baroid, CCI, & DSM. Pumped 23 bbl Hi-Vis spacer, followed by 353 bbls of 6% KCL brine w/ corrosion inhibitor, over displaced well by 56 bbls till returning fluid cleaned up. GPM-500 SPP-1446 psi. Flow check (static);POOH L/D 4.5" DP, vacuuming wiper balls through pipe, cleaning and re-doping threads and installing thread protectors F/7398' to current depth 5406'. R/D and released Geo-log hands;Hauled 11 bbls of solids to KGF G&I Cumulative: 1533 bbls Hauled 424 bbls of fluid to KGF G&I Cumulative: 6,222 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs p Side Wall Coring string RIH Drill Ahead 6 3/4'' Hole Section f/ 10,028' t/ 10,271' TD p Tested casing/abandonment plug T/1700 psi for 30 min on chart. ypp p p g p ppg Pump 123 bbls 15.3ppg PTA Cement @ 5 BPM 75 PSI FCP, Drop Disconnect Dart, Pump 5 bbls 15.3 ppg PTA Cement Continue Drilling 6 3/4'' Production Section f/ 8913' t/ 9037' ;M/U Mule Shoe RIH w/ 4.5'' IBTM Liner t/ pp Pumped 23 bbl Hi-Vis spacer, followed by 353 bbls of 6% KCL brine w/ corrosion inhibitor, pp M/U WLEG and RIH with 13 jts 4-1/2”, pppg 12.6#, L-80, IBT kill string to 518', gg M/U CBL Tool String RIH t/ 7 5/8'' Shoe @ 7701' Log out of the hole, L g gp Sonic Dipole and imager tool string Tagged TOC at 7404', gp ;Drill Ahead f/ 9037' t/ 9470' ;R/U Halliburton E Line M/Ugp g Slim Hole Caliper tool string RIH to bottom Log out of the hole to shoe, MW 9.25 ppg; f;Mud plug latched up pressured up t/ 2440 psi and released f/ Liner @pp gg ;Drill Ahead f/ 9777' t/ 10028' 2 BOP notice to AOGCC if need. g take 19 core samples; p g confirmed tag w/ 10K set down. 9/1/2021 POOH L/D 4.5" DP, vacuuming wiper balls through pipe, cleaning and re-doping threads and installing thread protectors F/5406' to 907' Correct displacement TOOH;Crew change. PTM, continue TOOH L/D 5'' DP to 565'. L/D 5 stands DP in derrick, XOs, 7 5/8'' csg scraper, M/U wear bushing puller, drain stack, S/O and engage WB, BOLDS, pull WB, L/D 2 jts DP to 4 1/2'' kill string at 522';M/U XO pup joint, tubing hanger, C/O to 4 1/2'' tubing elevators, land 4 1/2'' kill string with 8k on hanger, WLEG @ 540.6', WHR RILDS, L/D landing joint. PU 23K, SO 23K, Note: load out and start hauling equipment to SR.;R/U test equipment, attempt to test the 10 3/4'' x 7 5/8'' annulus against swell packer, with the test pump pressure up to 2500 psi, not holding, bled off to 1800 psi in 20 min, swell packer not fully engaged. bleed off pressure, R/D test equipment;Install TWC, PJSM, de-energized koomey, N/D BOPE, removed flow nipple and flow line from annular, un-chained stack, R/D choke & kill lines. Un-bolted stack from multi bowl and moved into position to be picked by crane. Notify AOGCC well work to be completed before required BOP test time.;Moved in dry hole tree & N/U, worked on prepping mud pump and cleaning pits modules for rig move. R/D floor handling equip. Installed pressure gauge on 10-3/4" x 7-5/8" annulus, opened annulus valve, had 200 psi on gauge, bled off pressure (water), cont. to monitor annulus.;Well head hand tested dry hole tree void T/250 psi Low for 5 min and 5000 psi High for 15 min (ok). Pressure tested tree T/5000 psi for 5 min (ok), pulled TWC and installed BPV in tree. R/D bails & saver sub from TDS, cont. working on mud pumps & pits.;Pressure washed rig floor, subs and floor equip. Removed all handling equip and subs off rig floor. R/D choke & kill line.;Crew change, held PTSM. Cont. R/D and prepping for rig move. R/D centrifuge and installed shipping block for travel, R/D, secured and prepped for move -pit module #3, mud pump skids 1 & 2, Gen #3, and gas buster. R/D bleeder and stand pipe manifold, clam shell, and test pump. removed handrails on;catwalk, disconnected accumulator hoses and secured in tray, started R/D Pason cables around rig. R/D Geronimo line. Pressure washed inside and out of stack and installed metal covers. R/D boiler module. Cont. loading out misc. equip and items onto floats. R/D shaker and installed shipping blocks,;started unplugging electrical interconnects around rig, installed doors on mud pump house skids, R/D wireless gas detectors sensors, horns, and lights. Inspected and secured derrick board for scoping derrick, R/D ODS weight indicator, R/D jumper hoses between hopper houses and equalizer;lines between pit modules. Removed cuttings shoots from shakers, lowered degasser into pit #4, R/D hole fill pump, lowered roof on pit module #3. Cont. R/D and prepping rig for move to Swanson river. Released rig from Whiskey Gulch #1 at 06:00 hrs. and moving to Swanson river SRU 241-33B.;Hauled 0 bbls of solids to KGF G&I Cumulative: 1533 bbls Hauled 0 bbls of fluid to KGF G&I Cumulative: 6,222 bbls Hauled 0 bbls of cement G&I Cumulative: 94 bbls Daily Metal: 0 lbs Cumulative: 0 lbs RILDS, ggp Released rig from Whiskey Gulch #1 at 06:00 hrs. Notify AOGCC well work to be completed before required BOP test time. gg p j land 4 1/2'' kill string with 8k on hanger, WLEG @ 540.6', attempt to test the 10 3/4'' x 7 5/8'' annulus against swell packer, with the test pumpgqp qp p pressure up to 2500 psi, not holding, bled off to 1800 psi in 20 min, swell packer not fully engaged. TD Shoe Depth: PBTD: Jts. 2 33 Yes X No X Yes No 60 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Type II 360 1.16 4.5 1.18 23.07 21.89 Type II 300 2.4 Hanger 13 5/8 DWC/C Cactus 25.46 Pup 10 3/4 45.5 L-80 DWC/C Vam 2.39 25.46 23.07 1,416.27 1,414.97 Casing 10 3/4 45.5 L-80 DWC/C Vam 1,389.51 1,414.97 82.89 1,499.16 1,416.27 Float collar 11 3/4 BTC Innovex 1.30 Casing 10 3/4 45.5 L-80 DWC/C Vam www.wellez.net WellEz Information Management LLC ver_04818br 4 58,000 Spud Mud 12 130 Type of Shoe:Innovex Casing Crew:Weatherford Ran 17 centralizers Cement to surface Bump Plug? 14:33 8/12/2021 0 1,500.001,510.00 1,414.00 CEMENTING REPORT Csg Wt. On Slips: 135/136.2 1340 94 Halliburton 15.8 4 Bump press 5 9.4 5 100 540FIRST STAGE10.5Tuned Prime 75 DWC/C Innovex 1.58 1,500.74 1,499.16 Csg Wt. On Hook:73,000 Type Float Collar:Innovex No. Hrs to Run: Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.Whiskey Gulch 1 Date Run 12-Aug-21 Spud Mud CASING RECORD County State Alaska Supv.R Pederson / J Richardson Setting Depths Ft. Min. PPG9.4 Shoe @ 1500.74 FC @ Top of Liner1,414.97 Floats Held Casing (Or Liner) Detail Shoe 11 3/4 Rotate Csg Recip Csg Component Size Wt. 74 bbls - bjm TD Shoe Depth: PBTD: Jts. 2 159 30 Yes X No X Yes No 4 Fluid Description: Liner hanger Info (Make/Model):Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm):Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface? Yes X No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: 19.83 I II 800 2.4 I II 145 1.24 6 22.70 20.28 Hanger 10 3/4 USS-CDC 0.45 20.28 1,196.89 1,219.59 22.70 7 5/8'' Casing Pup Jt 7 5/8 29.7 L-80 USS-CDC 2.42 7 5/8'' Casing Jts 7 5/8 29.7 L-80 USS-CDC 1,228.37 Swell Packer 9 5/8 29.7 L-80 USS-CDC 8.81 1,228.37 1,219.56 7,617.25 7,616.12 7 5/8'' Casing Jts 7 5/8 29.7 L-80 USS-CDC 6,387.75 7,616.12 82.40 7,699.65 7,617.25 Float Collar 8 5/8 BTC 1.13 7 5/8'' Casing jts 7 5/8 29.7 L-80 BTC www.wellez.net WellEz Information Management LLC ver_04818br 4 6% KCL Mud 12 333 Type of Shoe:Innovex Casing Crew:Weatherford CBL Bump Plug? 6:29 8/25/2021 ~1430' 7,701.677,710.00 CEMENTING REPORT Csg Wt. On Slips: 345.5/349.6 1240 0 Halliburton 15.8 30 Bump press 12.5 9.5 5 100 1240FIRST STAGE10.5Tune Primed 40 BTC 2.02 7,701.67 7,699.65 Csg Wt. On Hook: Type Float Collar:Innovex No. Hrs to Run: Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.Whiskey Gulch 1 Date Run 25-Aug-21 6% KCL Mud CASING RECORD County State Alaska Supv.R Pederson / J Riley Setting Depths Ft. Min. PPG9.5 Shoe @ 7701.67 FC @ Top of Liner7,616.12 Floats Held Casing (Or Liner) Detail Float Shoe 8 5/8 Rotate Csg Recip Csg Component Size Wt. TD Shoe Depth: PBTD: Jts. 68 Yes No X Yes No Fluid Description: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg)Rate (bpm):Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface?Yes X No Spacer returns? Yes X No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: PTA 580 1.24 1.19 7,540.23 7,539.04HBX Disconnect 5 1/2 8RD Cross Over Pup 4 1/2 12.6 L-80 IBTM X 8rd 6.00 7,546.23 7,540.23 www.wellez.net WellEz Information Management LLC ver_04818br 1510.5Tune Prime 5 10,268.0010,271.00 CEMENTING REPORT Mud 1:00 8/31/2021 7303' 15.3 128 Bump press Tagged Bump Plug? 75/85 2440 0 HalliburtonFIRST STAGE10.5Tune Prime 25 9.3 5 100 275 IBTM 2,721.77 10,268.00 7,546.23 Setting Depths Component Size Wt.Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.Whiskey Gulch 1 Date Run 30-Aug-21 CASING RECORD County State Alaska Supv.B Andersen / J Riley 6% KCL Mud Rotate Csg Recip Csg Ft. Min.PPG9.3 Shoe @ 10268 FC @ Top of Liner 7538.24 Casing (Or Liner) Detail 4.5'' Liner 4 1/2 12.6 L-80 7404' - bjm David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 09/13/2021 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WHISKEY GULCH 1 (PTD 221-046) **CONFIDENTIAL** MUDLOGS - EOW DRILLING REPORTS (08/09/2021 to 08/28/2021) 1.DAILY DRILLING REPORTS 2.FINAL EOW REPORT 3.DIGITAL DATA 4.LWD LOG PRINTS 5.MUDLOG PRINTS 6.SAMPLE PHOTOS 7.SHOW REPORTS Folder Contents: Please include current contact information if different from above. 09/13/2021 PTD: 2210460 E-Set: 35645 aa1-bola Hil�irp Majka, T.I.C. Date: 09/09/2021 David Douglas Hilcorp Alaska, LLC q e1 Sr. GeoTechnician 3800 CenterPoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com To: Alaska Oil & Gas Conservation Commission Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 RECEIVED S P 0 9 2021 AOGCC DATA TRANSMITTAL WHISKEY GULCH 1 (PTD 221-046) "CONFIDENTIAL" Washed and Dried Well Samples (08/28/2021) B Set (7 Boxes): WM-L Box SAWLS RMIRVAL (FEET ! MD) WHISKEY GULCH 1 BOX 1 OF 7 120' - 1500' MD WHISKEY GULCH 1 BOX 2 OF 7 1500' - 3000' MD WHISKEY GULCH 1 BOX 3 OF 7 3000' - 4260' MD WHISKEY GULCH 1 BOX 4 OF 7 4260' - 5670' MD WHISKEY GULCH 1 BOX 5 OF 7 5670' - 7290' MD WHISKEY GULCH 1 BOX 6 OF 7 7290' - 8760' MD WHISKEY GULCH 1 BOX 7 OF 7 8760' - 10271' MD (TD) Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received Bl �A. Date: 9 (C � �� I David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 09/07/2021 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WHISKEY GULCH 1 (PTD 221-046) **CONFIDENTIAL** FINAL OPEN HOLE WIRELINE LOGS Run 1 (08/11/2021) Run 2 (08/22/2021) Run 3 (08/29/2021) 1. BOREHOLE VOLUME (RUN 1 & 2: 08/11 & 22/2021) 2. BOREHOLE VOLUME (RUN 3: 08/29/2021) 3. ROTARY SW CORE TOOL (RUN 3: 08/29/2021) 4. WAVEFORM SONIC RAW & PROCESSED (RUN 1: 08/11/2021) 5. WAVEFORM SONIC RAW & PROCESSED (RUN 2: 08/22/2021) 6. WAVEFORM SONIC RAW & PROCESSED (RUN 3: 08/29/2021 7. EXT RANGE MICRO IMAGER RAW & PROCESSED (RUN 1 & 2: 08/11 & 22/2021) 8. EXT RANGE MICRO IMAGER RAW & PROCESSED (RUN 3: 08/29/2021) Folder Contents (Electronic Plots and Digital Data): Please include current contact information if different from above. Received By: 09/08/2021 37' (6HW By Abby Bell at 10:47 am, Sep 08, 2021 AOGCC David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 09/08/2021 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WHISKEY GULCH 1 (PTD 221-046) **CONFIDENTIAL** Cement Bond Log (08/29/2021) Folder Contents (Electronic Plots and Digital Data): Please include current contact information if different from above. Received By: 09/08/2021 37' (6HW By Abby Bell at 11:10 am, Sep 08, 2021 AOGCC David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 564-4422. Received By: Date: Date: 9/07/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WHISKEY GULCH 1 (PTD 221-046) **CONFIDENTIAL** FINAL LWD FORMATION EVALUATION LOGS (08/09/2021 to 08/28/2021) x DGR, GM, EWR-5, ADR, ALD, CTN (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey SFTP Transfer - Data Folders: Please include current contact information if different from above. Received By: 09/07/2021 37' (6HW By Abby Bell at 3:46 pm, Sep 07, 2021 AOGCC 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,271'N/A Casing Collapse Structural Conductor N/A Surface 2470 Intermediate 7500 Production Liner (P&A)N/A 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission 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 COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Frank Roach frank.roach@hilcorp.com 777-8413 9,333' ±7,451 (not yet tagged) ±6,554' 2312 N/A Length Size COMMISSION USE ONLY N/A Tubing Grade: Tubing MD (ft): N/A N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CONFIDENTIAL 20 AAC 25.280 ADL392666 221-046 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 N/A 50-231-20079-00-00 Hilcorp Alaska, LLC Whiskey Gulch Prospect Whiskey Gulch 1 PRESENT WELL CONDITION SUMMARY N/A TVD Burst N/A MD 8430 N/A 5210 120' 1,488' 6,805' 120' 1,501' 16" 10-3/4" 120' 7-5/8"7,702' 1,501' Perforation Depth MD (ft): 7,702' N/A 4-1/2" Perforation Depth TVD (ft): Tubing Size: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 8/31/2021 10,268'2,730' N/A 9,331' N/A Authorized Title: Drilling Manager Authorized Name: Monty Myers Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 8.31.2021 By Samantha Carlisle at 2:01 pm, Aug 31, 2021 321-438 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: 2021.08.31 13:39:32 -08'00' Monty M Myers BJM 9/1/21 X 10-404 DSR-8/31/21DLB 08/31/2021 dts 9/2/2021 JLC 9/2/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.02 13:32:43 -08'00' RBDMS HEW 9/3/2021 Whiskey Gulch #1 (PTD 221-046) Temporary Shutdown of Drilling or Completion Operations Hilcorp is requesting an “Operations Shutdown” under 20 AAC 25.072: Temporary shutdown of drilling or completion operations. The 6-3/4” hole section has been plugged and abandoned due to not finding producible oil in this leg. There is shallower gas potential. However, a plan needs to be developed on how to complete and test these zones. Steps that need to be completed in order to test the gas potential: xx Spacing exception to allow testing/production from any gas zones identified in the 7-5/8” cased hole section x Completion design and plan for testing of any identified zones x Temporary testing/flowback equipment sourced and available to allow for testing Hilcorp plans to resume the completion work no later than August 31, 2022. Upon shutdown, the well will be configured as shown in the attached schematic. A Dry-hole tree will be installed on the wellhead. 18.0 Run 4-1/2” Kill String x 6-3/4” hole section has been abandoned with a sacrificial liner and fully cemented to inside the 7-5/8” casing. x The eventual kill string was run in on drillpipe to tag the abandonment plug x The 7-5/8” casing envelope, including the abandonment plug, has been pressure tested to 1,700 psi using drilling mud. x Well has been swapped over to 6% KCl completion fluid. 18.1. POOH, LDDP, scraper and crossover. PU hanger and land string in hanger bowl. 18.2. Install packoff and test hanger void. 18.3. Test 9-5/8” x 7-5/8” annulus to 2,500 psi and chart for 30 minutes. 19.0 RDMO 19.1 Install BPV in wellhead 19.2 N/D BOPE 19.3 N/U dry-hole tree and test to 5,000 psi. 19.4 RDMO Hilcorp Rig #169 _____________________________________________________________________________________ Edited By: CJD 08-31-2021 Proposed Schematic Well: Whiskey Gulch 1 PTD: 221-046 API: 50-231-20079-00-00 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120’ 10-3/4” Surf Csg 45.5 L-80 DWC/C 9.950” Surf 1,501’ 7-5/8" Int. Csg 29.7 L-80 CDC 6.875” Surf 7,702’ 4-1/2" Abandonment Lnr 12.6 L-80 IBT 3.958” 7,538’ 10,268’ 4-1/2" Kill String 12.6 L-80 IBT 3.958” 0 500’ JEWELRY DETAIL No. Depth ID OD Item 1 1,220’ 6.875” 9.950” 7-5/8” Swell Packer 2 7,538’ 1.875” 4.500” Halliburton BHKA Disconnect Tool OPEN HOLE / CEMENT DETAIL 10-3/4” Est. TOC @ Surface (100% excess) Returns to surface (8/12/21) 7-5/8" Est. TOC @ 1000’ (40% excess) 4-1/2”Est. TOC @ 7,451 (20% OH excess w/100’left on top of liner) 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? W ill planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,271'N/A Casing Collapse Structural Conductor N/A Surface 2470 Intermediate 7500 Production Liner (FISH) 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission 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 COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Frank Roach frank.roach@hilcorp.com 777-8413 9,333'10,271'9,333'3168 N/A Length Size COMMISSION USE ONLY Tubing Grade:Tubing MD (ft): N/A N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CONFIDENTIAL 20 AAC 25.280 ADL392666 221-046 3800 Centerpoint Drive, Suite 1400, Acnhorage, AK 99503 N/A 50-231-20079-00-00 Hilcorp Alaska, LLC Whiskey Gulch Prospect Whiskey Gulch 1 PRESENT WELL CONDITION SUMMARY N/A TVD Burst N/A MD 8430 N/A 5210 120' 1,488' 6,805' 120' 1,501' 16" 10-3/4" 120' 7-5/8"7,702' 1,501' Perforation Depth MD (ft): 7,702' N/A Perforation Depth TVD (ft):Tubing Size: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 8/30/2021 N/A N/A Authorized Title: Drilling Manager Authorized Name: Monty Myers m n s 66 t _ c s Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 8.30.2021 By Samantha Carlisle at 10:48 am, Aug 30, 2021 321-436 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: 2021.08.30 10:05:15 -08'00' Monty M Myers 10-407X DLB 08/30/2021 Yes Provide 24 hrs notice for AOGCC to witness plug tag and pressure test. Steps 18.8-19.4 are not approved under this Sundry. Separate Sundry for Operations Shutdown or Suspension must be submitted prior to this work being done. BJM 8/31/21 8/29/21 X Bryan McLellan X bjm DSR-8/30/21 dts 8/31/2021 JLC 8/31/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.01 10:23:48 -08'00' RBDMS HEW 9/2/2021 16.0 Run 4-1/2” Abandonment String xx 6-3/4” hole section drilled to 10,271’ MD x 2-7/8” x 5” VBRs in both upper and lower ram cavities x Notify AOGCC inspector minimum 24 hrs prior to abandonment plug tag & pressure test for opportunity to witness per 20 AAC 25.112(h) 16.1. R/U Weatherford 4-1/2” casing running equipment. x Ensure 4-1/2” IBT x CDS 40 crossover on rig floor and M/U to FOSV. x R/U fill up line to fill liner while running. x Ensure all liner has been drifted prior to running. x Be sure to count the total # of joints before running. x Keep hole covered while R/U liner tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 16.2. P/U 4-1/2” muleshoe and RIH with 4-1/2” abandonment liner. x Fill liner while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x Install solid body centralizers on every other joint to 7-5/8” shoe. Leave the centralizers free floating. 16.3. Continue running 4-1/2” production liner 4-1/2” 12.6# L-80 IBT Data OD ID Drift Burst Collapse Tension Makeup 4.5” 3.958” 3.833” 8,430 psi 7,500 psi 288,000 lbs To Mark 16.4. MU Halliburton BHKA Disconnect Tool and RIH to 7-5/8” shoe. 16.5. Above 7-5/8” shoe, CBU to confirm string clear before entering openhole. Obtain PU/SO weights before running in openhole. Well Name: Whiskey Gulch 1 API Number: 50-231-20079-00-00 Current Status: Exploration Leg: N/A Regulatory Contact: Cody Dinger 777-8389 Permit to Drill Number: 221-046 First Call Engineer: Frank Roach (907) 777-8413 (O)(907) 854-2321 (C) Second Call Engineer: Monty Myers (907) 777-8431 (O)(907) 538-1168 (C) Centralizers 16.6. RIH from 7-5/8” shoe to TD. Adjust running speed as needed to keep from surging the hole. 16.7. Monitor PUW & SOW. Circulate BU if needed. Highlight zones of interest before running past, ex: coals 16.8. Swedge up and wash last stand to bottom. P/U 2-5’ off bottom. Note slack-off and pick-up weights. 16.9. Set liner slowly in and out of slips. 16.10. Stage pump rates up slowly to circulating rate. Circ and condition mud with liner on bottom. Circulate 2X bottoms up or until pressures stabilize, mud properties are correct, and the shakers are clean. Reduce the low-end rheology of the drilling fluid by adding water and thinners. 16.11. Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. 17.0 Cement 4-1/2” Abandonment Liner 17.1. Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 5-20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. x Which pump will be utilized for displacement (rig or cement unit), and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. x Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the liner during cmt operations until hole gets sticky 17.3. Test surface cmt lines to 4000 psi. 17.4. Pump 25 bbls of 10.5 ppg spacer. 17.5. Mix and pump cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 20% OH excess. Estimated Total Cement Volume: Cement Slurry Design: Section: Calculation: Vol (BBLS) Vol (ft3) 15.3 ppg SLURRY: 7-5/8” csg x 4-1/2” Liner annulus: 150’ x .02624 bpf = 3.94 22.1 15.3 ppg SLURRY: 6-3/4” OH x 4-1/2” annulus: (10271’ – 7701’) x .02459 bpf x 1.2 = 75.83 425.8 Total OUTSIDE: 79.77 bbl 447.9 ft3 15.3 ppg SLURRY: 4-1/2” 12.6# inside pipe: (10271’- 7551’) x .01522 bpf = 41.39 232.4 Total INSIDE: 41.39 bbl 232.4 ft3 15.3 ppg SLURRY: 5 bbls behind plug: 5.0 bbl 28.1 ft3 TOTAL CEMENT VOL: 126.16 bbl 708.4 ft3 Tail Slurry (10271’ to 7551’ MD) System Conventional Density 15.3 lb/gal Yield 1.24 ft3/sk Mixed Water 5.59 gal/sk Verified cement calcs - bjm 17.6. Drop disconnect plug and chase with 5bbls cement. Displace with 15bbls 10.5 ppg spacer and follow with drilling mud. If hole conditions allow – continue reciprocating liner throughout displacement. 17.7. Displace cement at max rate of 5-6 bbl/min. Reduce pump rate to 2-3 bpm 20 bbls prior to latching disconnect plug. 17.8. If elevated displacement pressures are encountered, position string at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.9. Bump the plug and pressure up to up as required by Halliburton procedure to disconnect from BHKA. Expected release pressure is 2,500 psi (±500 psi). 17.10. Bleed pressure to zero and watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.11. RD cement equipment on rig floor and pull uphole ~500’ clear abandonment top. 17.12. Drop wiper ball in drillstring. Circulate minimum 2x BU to clear any cement from drillpipe. Watch for spacer and cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 17.13. POOH and LD workstring adapter. If abandonment cement job was questionable or if cement returns were seen at surface, proceed to the contingency dedicated cleanout run prior to running the kill string (Section 20). Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if string is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure x Percent mud returns during job. If intermittent, note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” liner tally & liner and cement report to cdinger@hilcorp.com and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. 18.0 4-1/2” Cleanout/Kill string Run x Notify AOGCC inspector minimum 24 hrs prior to abandonment plug tag & pressure test for opportunity to witness per 20 AAC 25.112(h) x WOC for minimum of 12 hrs or until reaching a minimum of 200psi compressive strength (whichever is longer) before attempting tag and pressure test. 18.1 PU 4-1/2” WLEG and RIH with 4-1/2” 12.6# L-80 IBT pipe to 500’. 18.2 Cross over to drillpipe and run the cleanout assembly above the abandonment liner x Casing scrapers & brushes for 7-5/8” 29.7# casing x 4-1/2” DP to surface. 18.3 TIH & clean out well to ~250’ above top of abandonment string (+/- 7,551’ MD). x Circulate as needed on trip in if string begins to take weight. x Slow down ~500’ from stub. If close to gauge hole, TOC could be higher. x Circulate hi-vis sweeps as necessary to carry debris out of wellbore. 18.4 After wellbore has been cleaned out satisfactorily using mud, wash down slowly and tag TOC with bit, stacking 10k to confirm depth. x Tag of TOC above abandonment string satisfies 20 AAC 25.112(a)(1)(B) and 20 AAC 25.112(b)(1). x If unable to tag and stack out 10k before reaching abandonment string top, proceed to the the CIBP/dump-bailed cement will be required for abandonment. Continue washing down until either tagging liner stub or 10k WOB is achieved. 18.5 Pressure test 7-5/8” casing and abandonment plug to 1,700 psi (0.25 times 7-5/8” shoe TVD @ 6,801’ per 20 AAC 25.112(g)(2)) and chart for 30 minutes. 18.6 If tag or pressure test unsuccessful, proceed to the contingency CIBP/dump bail cement section (Section 21 below). 18.7 Displace drilling fluid in wellbore with a hi-vis pill followed by 6% KCl completion fluid. 18.8 POOH, LDDP, scraper and crossover. PU hanger and land string in hanger bowl. 18.9 Install packoff and test hanger void. 18.10 Test 9-5/8” x 7-5/8” annulus to 2,500 psi and chart for 30 minutes. 1700 psi PT with ~ 9.2 ppg Mud in wellbore provides ~300 psi above frac pressure at the shoe. -bjm Steps 18.8 - 19.4 are not permitted under this Sundry. A separate Sundry for Operations Shutdown or Suspension must be submitted for these steps. - bjm 19.0 RDMO 19.1 Install BPV in wellhead 19.2 N/D BOPE 19.3 N/U dry-hole tree and test to 5,000 psi. 19.4 RDMO Hilcorp Rig #169 20.0 Contingency 7-5/8” Dedicated Cleanout Run, Abandonment Plug Tag, and pressure test xx Notify AOGCC inspector minimum 24 hrs prior to abandonment plug tag & pressure test for opportunity to witness per 20 AAC 25.112(h) x WOC for minimum of 12 hrs or until reaching a minimum of 200psi compressive strength (whichever is longer) before attempting tag and pressure test. 20.1. If abandonment cement job was questionable or if cement returns were seen at surface, M/U casing clean out assy complete with casing scraper assembly. x 6-3/4” rock bit with open jets x Casing scrapers & brushes for 7-5/8” 29.7# casing x 4-1/2” DP to surface. 20.2. TIH & clean out well to ~250’ above top of abandonment string (+/- 7,551’ MD). x Circulate as needed on trip in if string begins to take weight. x Slow down ~500’ from stub. If close to gauge hole, TOC could be higher. x Circulate hi-vis sweeps as necessary to carry debris out of wellbore. 20.3. After wellbore has been cleaned out satisfactorily using mud, wash down slowly and tag TOC with bit, stacking 10k to confirm depth. x Tag of TOC above abandonment string satisfies 20 AAC 25.112(a)(1)(B) and 20 AAC 25.112(b)(1). x If unable to tag and stack out 10k before reaching abandonment string top, the CIBP/dump-bailed cement will be required for abandonment. Continue washing down until either tagging liner stub or 10k WOB is achieved. 20.4. Pressure test 7-5/8” casing and abandonment plug to 1,700 psi (0.25 times 7-5/8” shoe TVD @ 6,801’ per 20 AAC 25.112(g)(2)) and chart for 30 minutes. 20.5. Displace drilling fluid in wellbore with a hi-vis pill followed by 6% KCl completion fluid. 20.6. If tag or pressure test unsuccessful, proceed to the contingency CIBP/dump bail cement section (Section 21 below). 21.0 Contingency CIBP Set, Tag, Dump-Bail Cement, and Test xx Notify AOGCC inspector minimum 24 hrs prior to abandonment plug tag & pressure test for opportunity to witness per 20 AAC 25.112(h) x WOC for minimum of 12 hrs or until reaching a minimum of 200psi compressive strength (whichever is longer) before attempting tag and pressure test. 21.1. RU e-line and RIH w/CIBP and set 25’ above abandonment tag. Set down and confirm plug set. POOH and LD running tool. x CIBP needs to be within 25’ of abandonment tag to satisfy 20 AAC 25.112(c)(2)(C) 21.2. PU cement bailer assembly. Load w/cement and RIH to CIBP. Dump the equivalent of 25ft of cement on top of CIBP and POOH. 21.3. WOC and Pressure test 7-5/8” casing and abandonment plug to 1,700 psi (0.25 times 7-5/8” shoe TVD @ 6,801’ per 20 AAC 25.112(g)(2)) and chart for 30 minutes. 21.4. Proceed back to running Kill string in section 18. _____________________________________________________________________________________ Edited By: FVR 08-29-2021 Current Schematic Well: Whiskey Gulch 1 PTD: 221-046 API: 50-231-20079-00-00 TD = ±10,271’ (MD) / TD = ±9,333’ (TVD) 16” Ori g. KB Elev.: 18’ / GL Elev.: 220.6’ 7-5/8” 10-3/4” 44 2 6-3/4” Hole 9-7/8” Hole 13-1/2” Hole22 1 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor –Driven to Set Depth 84 X-56 Weld 15.01” Surf 120’ 10-3/4”Surf Csg 45.5 L-80 DWC/C 9.950”Surf 1,501’ 7-5/8"Int.Csg 29.7 L-80 CDC 6.875”Surf 7,702’ JEWELRY DETAIL No. Depth ID OD Item 1 1,220’6.875”9.950”7-5/8”Swell Packer OPEN HOLE / CEMENT DETAIL 10-3/4”Est. TOC @ Surface (100% excess) Returns to surface (8/12/21) 7-5/8"Est. TOC @ 1000’(40% excess) _____________________________________________________________________________________ Edited By: FVR 08-29-2021 Proposed Schematic Well: Whiskey Gulch 1 PTD: 221-046 API: 50-231-20079-00-00 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16” Conductor – Driven to Set Depth 84 X-56 Weld 15.01” Surf 120’ 10-3/4” Surf Csg 45.5 L-80 DWC/C 9.950” Surf 1,501’ 7-5/8" Int. Csg 29.7 L-80 CDC 6.875” Surf 7,702’ 4-1/2" Abandonment Lnr 12.6 L-80 IBT 3.958” 7,551’ 10,271’ 4-1/2" Kill String 12.6 L-80 IBT 3.958” 0 500’ JEWELRY DETAIL No. Depth ID OD Item 1 1,220’ 6.875” 9.950” 7-5/8” Swell Packer 2 7,551’ 1.875” 4.500” Halliburton BHKA Disconnect Tool OPEN HOLE / CEMENT DETAIL 10-3/4” Est. TOC @ Surface (100% excess) Returns to surface (8/12/21) 7-5/8" Est. TOC @ 1000’ (40% excess) 4-1/2” Est. TOC @ 7,451 (20% OH excess w/100’ left on top of liner) 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 Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Exploratory Field, Exploratory Pool, Whiskey Gulch 1 Hilcorp Alaska, LLC Permit to Drill Number: 221-046 revised Surface Location: 1553’ FSL, 1515’ FEL, Sec 23, T4S, R15W, SM, AK Bottomhole Location: 1047’ FNL, 1022’ FWL, Sec 25, T4S, R15W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Conditions of approval: Provide 24 hours’ notice for AOGCC to witness 4-1/2" liner pressure test and MITT and MITIA. Minimum kick tolerance is 15 bbls assuming 0.5 ppg kick above actual mud weight. Requires 14.8 ppg LOT EMW minimum at 7-5/8" casing shoe assuming planned mud weight of 9.3 ppg. Actual kick tolerance to be verified by AOGCC after performing LOT at surface casing shoe. BOP test to 3500 psi, annular test to 2500 psi, 7-day frequency. Provide daily operations reports to AOGCC every day. 6HHDGGLWLRQDOFRQGLWLRQVRIDSSURYDORQDWWDFKHGIRUP Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by Hilcorp Alaska, LLC in the attached application, the following well logs are also required for this well: Mudlog and cuttings samples are required per 20 AAC 25.071(a). Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of July, 2021. Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.30 17:01:07 -08'00' 1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 10,278' TVD: 9,317' 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 221' 15. Distance to Nearest Well Open Surface: x-168391 y- 2128221 Zone-4 203' to Same Pool: N/A 16. Deviated wells:Kickoff depth: 800 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 35 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Cond 16" 84# X-56 Weld 120' Surface Surface 120' 120' 13-1/2" 10-3/4" 45.5# L-80 DWC/C 1,500' Surface Surface 1,500' 1,484' 9-7/8" 7-5/8" 29.7# L-80 USS-CDC 7,940' Surface Surface 7,940' 7,021' 6-3/4" 4-1/2" 12.6# L-80 DWC/C-HT 2,545' 7,740' 6,825' 10,278' 9,317' Tieback 4-1/2" 12.6# L-80 DWC/C-HT 7,733' Surface Surface 7,733' 6,431' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned?Yes No 20. Attachments:Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email: Contact Phone: Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Whiskey Gulch 1 Whiskey Gulch Prospect Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. Total Depth MD (ft):Total Depth TVD (ft): 022224484 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL REVISED CONFIDENTIAL 20 AAC 25.005 L - 1898 ft3 / T - 171 ft3 3168 1553’ FSL, 1515' FEL, Sec 23, T4S, R15W, SM, AK 1047' FNL, 1022' FWL, Sec 25, T4S, R15W, SM, AK N/A 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Hilcorp Alaska, LLC 1553’ FSL, 1515' FEL, Sec 23, T4S, R15W, SM, AK ADL392666 18. Casing Program:Top - Setting Depth - BottomSpecifications 4099 GL / BF Elevation above MSL (ft): Cement Volume MDSize Plugs (measured): (including stage data) Driven L - 552 ft3 / T - 316 ft3 Effect. Depth MD (ft):Effect. Depth TVD (ft): LengthCasing Conductor/Structural Authorized Title: Authorized Signature: Authorized Name: Production Liner Intermediate Drilling Manager Monty Myers 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft):Perforation Depth MD (ft): 8/1/2021 2411' to the lease line from SHL Frank Roach frank.roach@hilcorp.com 777-8413 L - 415 ft3 / T - 104 ft3 Tieback Assy. 2349 es N ype of W L l R L 1b S Class: os N es No s N o D s s sD 84 o : well is p G S S 20 S S S es No s No S G E S es No s Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 7.23.2021 By Meredith Guhl at 9:59 am, Jul 23, 2021 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: 2021.07.23 09:00:02 -08'00' Monty M Myers See additional conditions of approval on transmission letter. Production from Whiskey Gulch No. 1 will commence only when an approved PA is in place. A copy of the decision and PA owners/landowners allocation schedule must be provided to AOGCC, prior to production. DLB X DSR-7/23/21 X (CO 790 /06/10/2021) X DLB 07/26/2021 50-231-20079-00-00 X 221-046 X X X BJM 7/27/2021 ),7/27UHVXOWVWREHUHYLHZHGDQGDFFHSWHGE\$2*&&EHIRUHUHVXPLQJGULOOLQJLQHDFKKROHVHFWLRQ (No chg.) (No chg.) DLB (No chg.)(No chg.) 381' FNL, 339' FWL, Sec 25, T4S, R15W, SM, AK 07/29/2021 DLB dts 7/30/2021 JLC 7/30/2021 6/30/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.30 17:00:22 -08'00' Whiskey Gulch #1 Drilling Program Confidential Exploration Tight Hole Rev 2 July 22, 2021 Contents 1.0 Well Summary ......................................................................................................................................... 2 2.0 Management of Change Information ...................................................................................................... 3 3.0 Tubular Program: ................................................................................................................................... 4 4.0 Drill Pipe Information: ............................................................................................................................ 4 5.0 Internal Reporting Requirements ........................................................................................................... 5 6.0 Planned Wellbore Schematic ................................................................................................................... 6 7.0 Drilling / Completion Summary .............................................................................................................. 7 8.0 Mandatory Regulatory Compliance / Notifications ................................................................................ 9 9.0 R/U and Preparatory Work ................................................................................................................... 11 10.0 N/U 21-1/4” Diverter .............................................................................................................................. 12 11.0 Drill 13-1/2” Hole Section ...................................................................................................................... 14 12.0 Run 10-3/4” Surface Casing................................................................................................................... 16 13.0 Cement 10-3/4” Surface Casing ............................................................................................................. 19 14.0 BOP N/U and Test ................................................................................................................................. 22 15.0 Drill 9-7/8” Hole Section ........................................................................................................................ 23 16.0 Run 7-5/8” Production Casing ............................................................................................................... 26 17.0 Cement 7-5/8” Production Casing ......................................................................................................... 29 18.0 Drill 6-3/4” Hole Section ........................................................................................................................ 32 19.0 Run 4-1/2” Production Liner ................................................................................................................. 35 20.0 Cement 4-1/2” Production Liner ........................................................................................................... 38 21.0 4-1/2” Liner Tieback Polish Run and Cleanout Run ............................................................................ 42 22.0 4-1/2” Tieback Run ................................................................................................................................ 42 23.0 RDMO .................................................................................................................................................... 43 24.0 BOP Schematic ...................................................................................................................................... 44 25.0 Wellhead Schematic ............................................................................................................................... 45 26.0 Days Vs Depth ........................................................................................................................................ 46 27.0 Geo-Prog ................................................................................................................................................ 47 28.0 Anticipated Drilling Hazards................................................................................................................. 48 29.0 Hilcorp Rig 169 Layout ......................................................................................................................... 51 30.0 FIT/LOT Procedure............................................................................................................................... 52 31.0 Choke Manifold Schematic .................................................................................................................... 53 32.0 Casing Design Information .................................................................................................................... 54 33.0 9-7/8” Hole Section MASP ..................................................................................................................... 55 34.0 6-3/4” Hole Section MASP ..................................................................................................................... 56 35.0 Spider Plot (Governmental Sections) .................................................................................................... 57 36.0 Surface Plat (As-Built NAD27) .............................................................................................................. 58 Page 2 Version 3 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 3 1.0 Well Summary Well Whiskey Gulch #1 Pad & Old Well Designation Whiskey Gulch Pad / grass roots well Planned Completion Type 4-1/2” Production tubing with Gas Lift Target Reservoir(s) Beluga/Tyonek Gas Sands w/ appraisal leg Planned Well TD, MD / TVD 10,278’ MD / 9,317’ TVD PBTD, MD / TVD 10,198’ MD / 9,238’ TVD Surface Location (Governmental) 1552.7’ FSL, 1514.9’ FEL, Sec 23, T4S, R15W, SM, AK Surface Location (NAD 27) X=168391.78 Y=2128221.41 Top of Productive Horizon (Governmental)381’ FNL, 339’ FWL, Sec 25, T4S, R15W, SM, AK TPH Location (NAD 27)X=170213.05, Y=2126184.71 BHL (Governmental) 1047’ FNL, 1022’ FWL, Sec 25, T4S, R15W, SM, AK BHL (NAD 27) X=170878.10, Y=2125500.00 AFE Number AFE Drilling Days 4 MOB, 53 DRLG AFE Completion Days 3 MOB, 7 COMP AFE Drilling Amount $6,949,031 AFE Completion Amount $894,698 Maximum Anticipated Pressure (Surface) 3168 psi Maximum Anticipated Pressure (Downhole/Reservoir) 4099 psi Work String 4-1/2” 16.6# S-135 CDS-40 RKB –GL 220.6’ (202.6 + 18) Ground Elevation 202.6’ BOP Equipment 11” 5M Annular BOP 11” 5M Double Ram 11” 5M Single Ram Page 2 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 1.0 Well Summary Well Whiskey Gulch #1 Pad & Old Well Designation Whiskey Gulch Pad / grass roots well Planned Completion Type 4-1/2” Production tubing with Gas Lift Target Reservoir(s) Beluga/Tyonek Gas Sands w/ appraisal leg Planned Well TD, MD / TVD 10,278’ MD / 9,317’ TVD PBTD, MD / TVD 10,198’ MD / 9,238’ TVD Surface Location (Governmental) 1552.7’ FSL, 1514.9’ FEL, Sec 23, T4S, R15W, SM, AK Surface Location (NAD 27) X=168391.78 Y=2128221.41 Top of Productive Horizon (Governmental) 1552.7’ FSL, 1514.9’ FEL, Sec 23, T4S, R15W, SM, AK TPH Location (NAD 27) X=168391.78, Y=2128221.41 BHL (Governmental) 1047’ FNL, 1022’ FWL, Sec 25, T4S, R15W, SM, AK BHL (NAD 27) X=170878.10, Y=2125500.00 AFE Number AFE Drilling Days 4 MOB, 53 DRLG AFE Completion Days 3 MOB, 7 COMP AFE Drilling Amount $6,949,031 AFE Completion Amount $894,698 Maximum Anticipated Pressure (Surface) 3168 psi Maximum Anticipated Pressure (Downhole/Reservoir) 4099 psi Work String 4-1/2” 16.6# S-135 CDS-40 RKB – GL 220.6’ (202.6 + 18) Ground Elevation 202.6’ BOP Equipment 11” 5M Annular BOP 11” 5M Double Ram 11” 5M Single Ram Superseded Whiskey Gulch #1 Changes to APD Mar 2021 Hilcorp Alaska, LLC Changes to Approved Permit to Drill Date: 03/22/2021 Subject: Changes to Approved Permit to Drill for Whiskey Gulch #1 File #: Whiskey Gulch #1 Drilling and Completion Program Any modifications to Whiskey Gulch #1 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be communicated and approved by the AOGCC. Sec Page Date Procedure Change Approved By Approved By All All 7/22/21 Updated Drilling Program (Version 2) to reflect As-Built coordinates in directional plan, hole section lengths, TDs FVR MMM 1.0 35 2 57 7/29/21 Updated Well Summary with correct TPH coordinates Updated Spider Plot to reflect correct TPH on map FVR MMM Approval: Monty Myers 7/29/2021 Drilling Manager Date Prepared: Frank Roach 7/29/2021 Drilling Engineer Date Page 3 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 2.0 Management of Change Information approved in advance by the AOGCC. Superseded Page 4 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 16” 15.01” 14.822” - 84 X-56 Weld 2980 1410 - 13-1/2”10-3/4”9.950” 9.875” 11.750” 45.5 L-80 DWC/C 5210 2470 1040 9-7/8”7-5/8”6.875” 6.750” 8.500” 29.7 L-80 USS-CDC 6880 4790 683 6-3/4”4-1/2”3.958” 3.833” 5.000” 12.6 L-80 DWC/C-HT 8430 7500 288 4.0 Drill Pipe Information: Hole Section OD (in) ID (in) TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) All 4-1/2”3.826 2.6875” 5.25” 16.6 S-135 CDS40 17,693 16,769 468k Cleanout 2-7/8”2.323 2.265” 3.438” 7.9 P-110 PH-6 16,896 16,082 194k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 5 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry tab. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates x Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp.com, Frank.Roach@hilcorp.com, and cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting x Notify EHS field coordinator. 1. This could be one of (3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don’t wait until an emergency to have to call around and figure it out!!!! a. John Coston: O: (907) 777-6726 C: (907) 227-3189 b. Jacob Nordwall: O: (907) 777-8418 C: (907) 748-0753 2. Spills: Keegan Fleming: O:907-777-8477 C:907-350-9439 x Notify Drlg Manager 1. Monty M Myers: O: 907-777-8431 C: 907-538-1168 x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to mmyers@hilcorp.com, Frank.Roach@hilcorp.com, and cdinger@hilcorp.com 5.6 Casing and Cmt report x Send casing and cement report for each string of casing to mmyers@hilcorp.com, Frank.Roach@hilcorp.com, and cdinger@hilcorp.com Page 6 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 6.0 Planned Wellbore Schematic Page 7 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 7.0 Drilling / Completion Summary WHISKEY GULCH #1 is a slant directional wildcat exploration well to be drilled off of the Whiskey Gulch pad in Anchor Point. The well will be drilled to test the gas and oil potential of Beluga, Tyonek, Hemlock and Cretaceous sands. An exploratory leg will be drilled to test the entire potential hydrocarbon structure through the Cretaceous sections. The base plan is deviated wellbore with a kickoff point at ~800’ MD. Maximum hole angle will be 35 deg before dropping to 11 deg and TD of the well will be 10,278’ TMD/ 9,317’ TVD. Drilling operations are expected to commence approximately August 1st, 2021. The Hilcorp Rig # 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to ~1,500’ MD / 1,484’ TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 – 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal / beneficial reuse depending on test results. General sequence of operations: 1. MOB Hilcorp Rig # 169 to well site 2. N/U diverter and test. 3. Drill 13-1/2” hole to 1,500’ MD. 4. POOH w/drill pipe. Perform logging. Perform cleanout run. 5. Run and cement 10-3/4” surface casing. 6. ND diverter, N/U & test 11” x 5M BOP. 7. Drill 9-7/8” hole to 7,940’ MD. 8. POOH w/drill pipe. Perform logging. Perform cleanout run. 9. Run and cement 7-5/8” production casing. 10. Drill 6-3/4” hole section to 10,278’ MD. Perform wiper trips as needed. 11. POOH w/drill pipe. Perform logging and coring. Perform cleanout run. 12. Run and cmt 4-1/2” production liner. 13. POOH laying down running tools. 14. PU clean out assembly and RIH. Displace well to 6% KCL completion fluid. 15. POOH and LD clean out assembly. 16. Run tieback/upper completion 17. N/D BOP, N/U dry hole tree, RDMO. py If cmt returns to surface are not observed, a Temp log will be run between 6 – 18 hrs after CIP to determine TOC. Necessary remedial–,pg action will then be discussed with AOGCC authorities. e expected to commence approximately August 1st, 2021. l wildcat exploration well t Page 8 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 Reservoir Evaluation Plan: 1. Surface hole: GR + Res 2. Intermediate hole: Triple Combo w/e-line sonic after TD 3. Production Hole: Triple Combo w/e-line sonic and sidewall coring after TD 4. Mud loggers from surface casing point to TD. Page 9 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x BOPs shall be tested at (2) week intervals during the drilling of WHISKEY GULCH #1. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements” x Ensure AOGCC approved drilling permits are posted on the rig floor and in Co Man office. Regulation Variance Requests: x 7-day BOP test frequency for exploration wells. Page 10 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure (psi) 13-1/2” x 21-1/4” x 2M Hydril MSP diverter Function Test Only 9-7/8” & 6-3/4” x 11” x 5M Annular BOP x 11” x 5M Double Ram o Blind ram in btm cavity x Mud cross x 11” x 5M Single Ram x 3-1/8” 5M Choke Line x 2-1/16” x 5M Kill line x 3-1/8” x 2-1/16” 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/3500 (Annular 2500 psi) Subsequent Tests: 250/3500 (Annular 2500 psi) x Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). x Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to spud. x 24 hours notice prior to testing BOPs. x 24 hours notice prior to casing running & cement operations. x Any other notifications required in APD. Additional requirements may be stipulated on APD and Sundry. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email: jim.regg@alaska.gov Bryan McLellan / Petroleum Engineer / (O): 907-793-1226 / Email: bryan.mclellan@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 11 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 9.0 R/U and Preparatory Work 9.1 Set 16” conductor at +/-120’ below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install slip-on 16-3/4” 3M “A” section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Hilcorp Rig # 169, spot service company shacks, spot & R/U company man & toolpusher offices. 9.7 RU Mud loggers. Mud loggers are required on surface hole section taking 30’ samples 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 13-1/2” hole section. 9.10 Install 6” liners in mud pumps. x HHF-1000 mud pumps are rated at 2550 psi (85%) / 441 gpm (100%) at 120 spm with 6” liners. Page 12 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 10.0 N/U 21-1/4” Diverter 10.1 N/U 21-1/4” Diverter x N/U 21-1/4” diverter “T”. x Knife gate, 16” diverter line. x Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. Ensure to notify AOGCC inspector to witness function test of diverter. x NOTE: Ensure closing time on diverter annular is in line with API RP 64: o Annular element ID 20” or smaller: Less than 30 seconds o Annular element ID greater than 20”: Less than 45 seconds 10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the vent line tip. “Warning Zone” must include: x A prohibition on vehicle parking x A prohibition on ignition sources or running equipment x A prohibition on staged equipment or materials x Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set wear bushing in wellhead. Page 13 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 10.5 Rig 169 Orientation: Note: Actual layout may be different on location Page 14 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 11.0 Drill 13-1/2” Hole Section 11.1 P/U 13-1/2” directional drilling assy: x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Workstring will be 4.5” 16.6# S-135 CDS40 11.2 4-1/2” Workstring & HWDP will come from Hilcorp. 11.3 Begin drilling out from 16” conductor at reduced flow rates to avoid broaching the conductor. 11.4 Drill 13-1/2” hole section to 1,500’ MD/ 1,484’ TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. x Utilize past experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. x Keep swab and surge pressures low when tripping. x Make wiper trips every 500’ or every couple days unless hole conditions dictate otherwise. x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. x TD the hole section in a good shale between 1,400’ and 1,600’MD. x Take MWD surveys every stand drilled (60’ intervals). 11.5 13-1/2” hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8 – 9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 120-1500’8.8 – 9.5 85-150 20 - 40 25 - 45 <10 8.5-9.0 Note: 8.46 ppg EMW needed. DLB y()pp W spud mud at 8.8 ppg. 8.8 – 9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud– Page 15 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 System Formulation: Aquagel + FW spud mud Product Concentration FRESH WATER SODA ASH AQUAGEL CAUSTIC SODA BARAZAN D+ BAROID 41 PAC-L /DEXTRID LT ALDACIDE G X-TEND II 0.905 bbl 0.5 ppb 12-15 ppb 0.1 ppb (9 pH) as needed as required for weight if required for <12 FL 0.1 ppb 0.02 ppb 11.6 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16” conductor shoe. 11.7 TOH with the drilling assy, handle BHA as appropriate. 15.1 RU E-Line and perform wireline logging plan. 11.8 PU 13-1/2” cleanout assembly and RIH to TD, noting any tight spots along the way. CBU at least once at TD to ensure hole is clean for casing run. POOH and LD cleanout assembly. Page 16 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 12.0 Run 10-3/4” Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 10-3/4” casing running equipment. x Ensure 10-3/4” DWC x CDS 40 XO on rig floor and M/U to FOSV. x R/U fill-up line to fill casing while running. x Ensure all casing has been drifted on the location prior to running. x Be sure to count the total # of joints on the location before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 12.3 P/U shoe joint. Visually verify no debris inside joint. 12.4 Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ float shoe bucked on (thread locked). x (1) Joint with coupling thread locked. x (1) Joint with float collar bucked on pin end & thread locked. x Install (2) centralizers on shoe joint over a stop collar. 10’ from each end. x Install (1) centralizer, mid tube on thread locked joint and on FC joint. x Ensure proper operation of float equipment. 12.5 Continue running 10-3/4” surface casing x Fill casing while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x Install (1) centralizer every other joint to 300’. Do not run any centralizers above 300’ in the event a top out job is needed. x Utilize a collar clamp until weight is sufficient to keep slips set properly. 10-3/4” 45.5# DWC/C M/U torques Casing OD Minimum Maximum Yield Torque 10-3/4”35,900 ft-lbs 42,200 ft-lbs 48,500 ft-lbs pppyp Install (1) centralizer every other joint to 300’. Do not run any centralizers above 300’ in the() y event a top out job is needed. Page 17 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 Page 18 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 19 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 13.0 Cement 10-3/4” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface. x Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 30 bbls of 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume + 50% open hole excess. Job will consist of lead & tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 16” Conductor x 10-3/4” casing annulus: 120’ x .10660 bpf = 12.79 71.8 12.0 ppg LEAD: 13-1/2” OH x 10-3/4” Casing annulus: (1000’ – 120’) x .06478 bpf x 1.5 = 85.51 480.1 Total LEAD: 98.31 bbl 551.9 ft3 15.4 ppg TAIL: 13-1/2” OH x 10-3/4” Casing annulus: (1500’- 1000’) x .06478 bpf x 1.5 = 48.59 272.8 15.4 ppg TAIL: 10-3/4” Shoe track: 80 x .09617 bpf = 7.69 43.2 Total TAIL: 56.28 bbl 316.0 ft3 TOTAL CEMENT VOL: 154.59 bbl 867.9 ft3 Verified cement calcs - bjm Page 20 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 Cement Slurry Design: 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets “sticky”, land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 1500’-80’ = 1420’x .09617 bpf = 137 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.13 Do not overdisplace by more than ½ shoe track volume. Total volume in shoe track is 7.7 bbls. x Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12 – 18 hours after CIP. x Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5”. 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. Lead Slurry (1000’ MD to surface) Tail Slurry (1500’ to 1000’ MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.40 ft3/sk 1.16 ft3/sk Mixed Water 14.25 gal/sk 5.04 gal/sk Mixed Fluid 14.25 gal/sk 5.04 gal/sk Page 21 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to cdinger@hilcorp.com and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 22 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 14.0 BOP N/U and Test 14.1 ND Diverter line and diverter 14.2 N/U multi-bowl wellhead assy. Install 10-3/4” packoff P-seals. Test to 3000 psi. 14.3 N/U 11” x 5M BOP as follows: x BOP configuration from Top down: 11” x 5M annular BOP/11” x 5M double ram /11” x 5M mud cross/11” x 5M single ram x Double ram should be dressed with 2-7/8” x 5” variable bore rams in top cavity, blind ram in btm cavity. x Single ram should be dressed with 2-7/8” x 5” variable bore rams x N/U bell nipple, install flowline. x Install (2) manual valves & a check valve on kill side of mud cross. x Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2” BOP test assy, land out test plug (if not installed previously). x Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. x Ensure to leave “B” section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.0 ppg 6% KCL PHPA mud system. 14.8 R/U mud loggers for production hole section. 14.9 Rack back as much 4-1/2” DP in derrick as possible to be used while drilling the hole section. 14.10 Install 5-1/2” liners in mud pumps. x HHF-1000 mud pumps are rated at 3036 psi (85%) / 370 gpm (100%) at 120 spm with 5-1/2” liners. x 9.0 ppg 6% KCL PHPA mud system. Page 23 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 15.0 Drill 9-7/8” Hole Section 15.2 Pull test plug, run and set wear bushing 15.3 Ensure BHA components have been inspected previously. 15.4 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.5 TIH, Conduct shallow hole test of MWD and confirm all LWD functioning properly. 15.6 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.7 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.8 Workstring will be 4.5” 16.6# S-135 CDS40. Ensure to have enough 4-1/2” DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 15.9 9-7/8” hole section mud program summary: Weighting material to be used for the hole section will be barite, salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: MD Mud Weight Viscosity Plastic Viscosity Yield Point pH HPHT 1,500’- 7,940’ 9.0 – 10.0 40-53 15-25 15-25 8.5-9.5 11.0 Note: 8.46 ppg EMW needed. DLB 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Page 24 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 System Formulation: 6% KCL EZ Mud DP Product Concentration Water KCl Caustic BARAZAN D+ EZ MUD DP DEXTRID LT PAC-L BARACARB 5/25/50 BAROID 41 ALDACIDE G BARACOR 700 BARASCAV D 0.905 bbl 22 ppb (29 K chlorides) 0.2 ppb (9 pH) 1.25 ppb (as required 18 YP) 0.75 ppb (initially 0.25 ppb) 1-2 ppb 1 ppb 15 - 20 ppb (5 ppb of each) as required for a 9.0 – 10.0 ppg 0.1 ppb 1 ppb 0.5 ppb (maintain per dilution rate) 15.10 TIH w/ 9-7/8” directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.11 R/U and test casing to 3000 psi / 30 min. Ensure to record volume / pressure and plot on LOT graph. AOGCC requirement is 50% of burst. 10-3/4” burst is 5210 psi / 2 = 2605 psi. 15.12 Drill out shoe track and 20’ of new formation. 15.13 CBU and condition mud for LOT. 15.14 Conduct LOT. Target value is 14.8 ppg EMW. Note: Offset field test data predicts frac gradient at the 10-3/4” shoe to be between 12.5 – 15.5 ppg EMW. A 14.8 ppg LOT results in a 5.5 ppg kick margin and a >15 bbl kick tolerance volume while drilling with the planned MW of 9.3 ppg. Kick tolerance Factor = (14.8-9.3)X(1484/7021) = 1.16 15.15 Drill 9-7/8” hole section to 7,940’ MD / 7,021’ TVD x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at 500 - 600 gpm. Ensure shaker screens are set up to handle this flowrate. x Keep swab and surge pressures low when tripping. x Make wiper trips every 1000’ unless hole conditions dictate otherwise. x On the third wiper trip (around 4,500’ MD), trip back to the 10-3/4” shoe to split the hole section in half x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. x Take MWD surveys every 100’ drilled. Surveys can be taken more frequently if deemed necessary. x Take (3) sets of formation samples every 20’. A 15 bbl minimum KT is required, so minimum of 14.8 ppg LOT EMW is required to drill the well as designed.-bjm Target value is 14.8 ppg EMW. gpp AOGCC requirement is 50% of burst. Review LOT results with AOGCC before proceeding. bjm Page 25 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 10-3/4” shoe. 15.17 TOH with the drilling assy, standing back drill pipe. 15.18 LD BHA 15.19 RU E-Line and perform wireline logging plan. 15.20 RD E-Line. PU 9-7/8” clean out BHA, and TIH to TD. 15.21 Pump sweep, CBU and condition mud for casing run. 15.22 POOH and LD BHA 15.23 Install 7-5/8” casing rams in BOP stack and test. Install 7-5/8” casing rams in BOP stack and test. Page 26 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 16.0 Run 7-5/8” Production Casing 16.1. R/U Weatherford 7-5/8” casing running equipment. x Ensure 7-5/8” CDC x CDS 40 crossover on rig floor and M/U to FOSV. x R/U fill up line to fill casing while running. x Ensure all casing has been drifted prior to running. x Be sure to count the total # of joints before running. x Keep hole covered while R/U equipment. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). x (1) joint casing, threadlocked (coupling also thread locked) x (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). x Solid body centralizers will be pre-installed on shoe joint an FC joint. x Leave centralizers free floating so that they can slide up and down the joint. x Ensure proper operation of float shoe and float collar. x Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 7-5/8” production casing x Fill casing while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x Install solid body centralizers on every joint across zones of interest, TBD after LWD. x Install solid body centralizers on every other joint to 10-3/4” shoe. Leave the centralizers free floating. x Pick up swell packer and place in string at approximately 250’ above 10-3/4” surface casing shoe depth (~1,250’ MD). 16.5. Continue running 7-5/8” production casing 7-5/8” 29.7# CDC M/U torques Casing OD Minimum Maximum Yield Torque 7-5/8”14,000 ft-lbs 17,000 ft-lbs 20,900 ft-lbs () p ( p g Solid body centralizers will be pre-installed on shoe joint an FC joint. pppyp Install solid body centralizers on every joint across zones of interest, TBD after LWD. x yyj Install solid body centralizers on every other joint to 10-3/4” shoe. Leave the centralizers free floating. Page 27 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 Page 28 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 16.6. Run in hole w/ 7-5/8” casing to the 10-3/4” casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight, and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/ casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. 16.12. Monitor PUW & SOW. Circulate BU if needed. Highlight zones of interest before running past, ex: coals 16.13. Swedge up and wash last stand before picking up hanger/landing joint. Note slack-off and pick- up weights. 16.14. P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 16.15. Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 16.16. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low-end rheology of the drilling fluid by adding water and thinners. 16.17. Rotate and reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 29 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 17.0 Cement 7-5/8” Production Casing 17.1. Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. x Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. x Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations until hole gets sticky. 17.3. R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 17.4. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.5. Test surface cmt lines to 4500 psi. 17.6. Pump remaining 30 bbls 12.5 ppg Mud Push spacer. 17.7. Drop bottom plug. Mix and pump cmt per below recipe. 17.8. Cement volume based on annular volume + 40% open hole excess. Job will consist of lead & tail, TOC brought to 500’ above surface casing shoe. Page 30 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 Estimated Total Cement Volume: Cement Slurry Design: 17.9. Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets “sticky”, land the hanger on seat and continue with the cement job. 17.10. After pumping cement, drop top plug and displace cement with mud. Displace at max rate of 5 bbl/min. 17.11. Displacement calculation: 7933’- 80’ = 7853’ x .04592 bpf = 361 bbls 17.12. If hole conditions allow – continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 10-3/4” casing x 7-5/8” casing annulus: (1500’ – 1000’) x .03969 bpf = 19.85 111.4 12.0 ppg LEAD: 9-7/8” OH x 7-5/8” Casing annulus: (7440’ – 1500’) x .03825 bpf x 1.4 = 318.09 1786.0 Total LEAD: 337.94 bbl 1897.4 ft3 15.4 ppg TAIL: 9-7/8” OH x 7-5/8” Casing annulus: (7940’- 7440’) x .03825 bpf x 1.4 = 26.78 150.3 15.4 ppg TAIL: 7-5/8” Shoe track: 80 x .04592 bpf = 3.67 20.6 Total TAIL: 30.45 bbl 171.0 ft3 TOTAL CEMENT VOL: 368.39 bbl 2068.3 ft3 Lead Slurry (7440’ MD to 1000’ MD) Tail Slurry (7940’ to 7440’ MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.4 ft3/sk 1.24 ft3/sk Mixed Water 14.09 gal/sk 5.58 gal/sk Mixed Fluid 14.09 gal/sk 5.58 gal/sk Verified cement calcs - bjm Page 31 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 17.13. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.14. Do not overdisplace by more than ½ shoe track. Shoe track volume is 3.7 bbls. 17.15. Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. Note amount of fluid returned after bumping plug and releasing pressure. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 17.16. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.17. R/D cement equipment. Flush out wellhead with FW. 17.18. Back out and L/D landing joint. Flush out wellhead with FW. 17.19. M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 17.20. Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job. If intermittent, note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to cdinger@hilcorp.com and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 32 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 18.0 Drill 6-3/4” Hole Section 15.24 Pull test plug, run and set wear bushing 15.25 Ensure BHA components have been inspected previously. 15.26 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.27 TIH, Conduct shallow hole test of MWD and confirm all LWD functioning properly. 15.28 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.29 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.30 Workstring will be 4-1/2” 16.6# S-135 CDS40. Ensure to have enough 4-1/2” DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 15.31 6-3/4” hole section mud program summary: Weighting material to be used for the hole section will be barite, salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: MD Mud Weight Viscosity Plastic Viscosity Yield Point pH HPHT 7,940’- 10,278’ 9.0 – 10.0 40-53 15-25 15-25 8.5-9.5 11.0 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Note: 8.46 ppg EMW minimum needed. DLB Replace casing rams with VBRs and test. bjm Page 33 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 System Formulation: 6% KCL EZ Mud DP Product Concentration Water KCl Caustic BARAZAN D+ EZ MUD DP DEXTRID LT PAC-L BARACARB 5/25/50 BAROID 41 ALDACIDE G BARACOR 700 BARASCAV D 0.905 bbl 22 ppb (29 K chlorides) 0.2 ppb (9 pH) 1.25 ppb (as required 18 YP) 0.75 ppb (initially 0.25 ppb) 1-2 ppb 1 ppb 15 - 20 ppb (5 ppb of each) as required for a 9.0 – 10.0 ppg 0.1 ppb 1 ppb 0.5 ppb (maintain per dilution rate) 15.32 TIH w/ 6-3/4” directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.33 R/U and test casing to 3500 psi / 30 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC requirement is 50% of burst. 7-5/8” burst is 6890 psi / 2 = 3445 psi. 15.34 Drill out shoe track and 20’ of new formation. 15.35 CBU and condition mud for LOT. 15.36 Conduct LOT. Target value is 13.5 ppg EMW. Note: Offset field test data predicts frac gradient at the 7-5/8” shoe to be between 12.5 – 15.5 ppg EMW. A 13.5 ppg LOT results in a 4.5 ppg kick margin and a >15 bbl kick tolerance volume while drilling with the planned MW of 9.5 ppg. Kick tolerance = (13.5-9.5)X(7021/9317) = 3.01 15.37 Drill 6-3/4” hole section to 10,278’ MD / 9,317’ TVD x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at 400 - 500 gpm. Ensure shaker screens are set up to handle this flowrate. x Keep swab and surge pressures low when tripping. x Make wiper trips every 1000’ unless hole conditions dictate otherwise. x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. x Take MWD surveys every 100’ drilled. Surveys can be taken more frequently if deemed necessary. x Take (3) sets of formation samples every 20’. 15.38 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8” shoe. ppg ppg e drilling with the planned MW of 9.5 ppg. 13.5 ppg EMW. Review LOT results with AOGCC before proceeding. - bjm Page 34 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 15.39 TOH with the drilling assy, standing back drill pipe. 15.40 LD BHA 15.41 RU E-Line and perform wireline logging plan. 15.42 RD E-Line. PU 6-3/4” clean out BHA, and TIH to TD. 15.43 Pump sweep, CBU and condition mud for casing run. 15.44 POOH and LD BHA 15.45 2-7/8” x 5-1/2” VBRs previously installed in BOP stack and tested with 4-1/2” test joint. 2-7/8” x 5-1/2” VBRs previously installed in BOP stack and tested with 4-1/2” test joint. Page 35 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 19.0 Run 4-1/2” Production Liner 16.6. R/U Weatherford 4-1/2” casing running equipment. x Ensure 4-1/2” DWC/C-HT x CDS 40 crossover on rig floor and M/U to FOSV. x R/U fill up line to fill liner while running. x Ensure all liner has been drifted prior to running. x Be sure to count the total # of joints before running. x Keep hole covered while R/U liner tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 16.7. P/U shoe joint, visually verify no debris inside joint. 16.8. Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). x (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). x (1) Joint with Baker landing collar bucked on pin end & threadlocked. x Solid body centralizers will be pre-installed on shoe joint an FC joint. x Leave centralizers free floating so that they can slide up and down the joint. x Ensure proper operation of float shoe and float collar. x Utilize a collar clamp until weight is sufficient to keep slips set properly 16.9. Continue running 4-1/2” production liner x Fill liner while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x Install solid body centralizers on every joint across zones of interest, TBD after LWD. x Install solid body centralizers on every other joint to 7-5/8” shoe. Leave the centralizers free floating. 16.10. Continue running 4-1/2” production liner 4-1/2” 12.6# DWC/C-HT M/U torques Casing OD Minimum Maximum Yield Torque 4-1/2”5,800 ft-lbs 6,500 ft-lbs 9,240 ft-lbs pppyp Install solid body centralizers on every joint across zones of interest, Install solid body centralizers on every other joint to 7-5/8” shoe. yyj () g p Solid body centralizers will be pre-installed on shoe joint an FC joint. Page 36 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 Page 37 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 16.18. Run in hole w/ 4-1/2” liner to the 7-5/8” casing shoe. 16.19. Fill the liner with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 16.20. Obtain slack off weight, PU weight, rotating weight, and torque of the liner. 16.21. Circulate 2X bottoms up at shoe, ease liner thru shoe. 16.22. Continue to RIH w/ liner no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.23. Set liner slowly in and out of slips. 16.24. PU 4-1/2” X 7-5/8” Baker liner hanger/LTP assembly. RIH 1 stand and circulate one liner volume to clear string. Obtain slack off weight, PU weight, rotating weight, and torque parameters of the liner. 16.25. Continue running in hole at slow speeds to avoid surging well. Target 20 ft/min and adjust slower as hole conditions dictate. 16.26. Monitor PUW & SOW. Circulate BU if needed. Highlight zones of interest before running past, ex: coals 16.27. Swedge up and wash last stand to bottom. P/U 2-5’ off bottom. Note slack-off and pick-up weights. 16.28. Stage pump rates up slowly to circulating rate. Circ and condition mud with liner on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low-end rheology of the drilling fluid by adding water and thinners. 16.29. Rotate and reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 38 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 20.0 Cement 4-1/2” Production Liner 17.21. Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. x Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. x Document efficiency of all possible displacement pumps prior to cement job. 17.22. Attempt to rotate and reciprocate the liner during cmt operations until hole gets sticky 17.23. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.24. Test surface cmt lines to 4500 psi. 17.25. Pump remaining 30 bbls 12.5 ppg Mud Push spacer. 17.26. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 40% OH excess. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 7-5/8” csg x 4-1/2” drillpipe annulus: 200’ x .02624 bpf = 5.25 29.5 12.0 ppg LEAD: 7-5/8” csg x 4-1/2” liner annulus: 200’ x .02624 bpf = 5.25 29.5 12.0 ppg LEAD: 6-3/4” OH x 4-1/2” annulus: (9778’ – 7940’) x .02459 bpf x 1.4 = 63.27 355.3 Total LEAD: 73.77 bbl 414.2 ft3 15.4 ppg TAIL: 6-3/4” OH x 4-1/2” annulus: (10278’- 9778’) x .02459 bpf x 1.4 = 17.21 96.6 15.4 ppg TAIL: 4-1/2” Shoe track: 80 x .01522 bpf = 1.22 6.8 Total TAIL: 18.43 bbl 103.5 ft3 TOTAL CEMENT VOL: 92.20 bbl 517.7 ft3 Verified cement calcs bjm p p 40% OH excess. Page 39 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 Cement Slurry Design: 17.27. Drop drillpipe dart and displace with drilling mud. If hole conditions allow – continue rotating and reciprocating liner throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.28. Displace cement at max rate of 5 bbl/min. Reduce pump rate to 2-3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point. 17.29. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.30. Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger (ensure pressure is above nominal setting pressure, but below pusher tool activation pressure). Hold pressure for 3-5 minutes. 17.31. Slack off total liner weight plus 30k to confirm hanger is set. 17.32. Do not overdisplace by more than ½ shoe track. Shoe track volume is 1.2 bbls. 17.33. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.34. Pick up to expose dogs and set liner top packer. 17.35. Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS nipple. Bump up pressure as req’d to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack-off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 17.36. Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. Lead Slurry (9778’ MD to 7740’ MD) Tail Slurry (10278’ to 9778’ MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.4 ft3/sk 1.24 ft3/sk Mixed Water 14.09 gal/sk 5.58 gal/sk Mixed Fluid 14.09 gal/sk 5.58 gal/sk Page 40 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 17.37. Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 17.38. RD cementers and flush equipment. POOH, LDDP and running tool. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 17.39. If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 17.40. NOTE: Some hole conditions may require movement of the drillpipe to “work” the torque down to the setting tool. 17.41. After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. 17.42. WOC minimum of 12 hours, test liner to 3500 psi and chart for 30 minutes. Page 41 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if liner is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job. If intermittent, note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” liner tally & liner and cement report to cdinger@hilcorp.com and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 42 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 21.0 4-1/2” Liner Tieback Polish Run and Cleanout Run 18.1. PU liner tieback polish mill assy per Baker rep and RIH on drillpipe. 18.2. RIH to top of liner assembly and establish parameters. Polish tieback receptacle per Baker procedure. 18.3. POOH, and LD polish mill. 18.4. M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. x 3-1/2” bit or mill x Casing scraper & brush for 4-1/2” 12.6# tubulars x +/- 5100’ 2-7/8” PH-6 workstring. x Casing scraper & brush for 7-5/8” 29.7# casing x 4-1/2” DP to surface. 18.5. TIH & clean out well to landing collar (+/- 6,250’ MD). x Circulate as needed on trip in if string begins to take weight. x Circulate hi-vis sweeps as necessary to carry debris out of wellbore. x Ensure 3-1/2” bit is worked down to the landing collar. x Space out the cleanout BHA so that the 3-1/2” bit reaches the 4-1/2” landing collar when crossover/7-5/8” casing scraper is +/- 30’ above the 4-1/2” liner top. 18.6. After wellbore has been cleaned out satisfactorily using mud, test casing/liner envelope to 3500 psi / 30 min. Ensure to chart record casing test. 18.7. Displace drilling fluid in wellbore with a hi-vis pill followed by 6% KCl completion fluid. 18.8. POOH, LDDP and workstring. Clean and clear rig floor in preparation for running tieback. 22.0 4-1/2” Tieback Run 19.1 PU 4-1/2” tieback assembly and RIH with 4-1/2” 17# L-80 CDC HTQ casing. 19.2 No-go tieback seal assembly in liner PBR and mark pipe. PU pup joint(s) if necessary to space out tieback seals in PBR. 19.3 PU hanger and land string in hanger bowl. Note distance of seals from no-go. 19.4 Install packoff and test hanger void. Provide 24 hrs notice to AOGCC to witness test. Displace drilling fluid in wellbore with a hi-vis pill followed by 6% KCl completion fluid. 8.65 ppg fluid Page 43 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 19.5 Test 4-1/2” liner and tieback to 3,500 psi and chart for 30 minutes. 19.6 Test 7-5/8” x 4-1/2” annulus to 2,500 psi and chart for 30 minutes. 23.0 RDMO 20.1 Install BPV in wellhead 20.2 N/D BOPE 20.3 N/U dry-hole tree or (if space permitting) full tree and test to 5,000 psi. 20.4 RDMO Hilcorp Rig #169 Provide 24 hrs notice to AOGCC to witness MITIA and MITT. bjm Sundry required for perforating. Perforations will only be allowed in the productive interval described in CO 790. - bjm Page 44 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 24.0 BOP Schematic Page 45 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 25.0 Wellhead Schematic Page 46 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 26.0 Days Vs Depth Page 47 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 27.0 Geo-Prog Page 48 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 28.0 Anticipated Drilling Hazards 13-1/2” Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP between 25 – 45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of ~50 - ~60 lbs/100ft2 to combat this issue. Maintain low flow rates for the initial 200’ of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 – 30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. DLB H2S: H2S is not present in this hole section. Page 49 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 9-7/8” Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Given the volume of losses experienced in KU 42-12 when drilling through Pool 6, ensure all LCM inventory is fully stocked before drilling out surface casing. Hole Cleaning: Maintain rheology w/ viscosifier as necessary. Sweep hole w/ 20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP between 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KCl in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. x Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. x Use asphalt-type additives to further stabilize coal seams. x Increase fluid density as required to control running coals. x Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. DLB H2S: H2S is not present in this hole section. Page 50 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 6-3/4” Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Given the volume of losses experienced in KU 42-12 when drilling through Pool 6, ensure all LCM inventory is fully stocked before drilling out surface casing. Hole Cleaning: Maintain rheology w/ viscosifier as necessary. Sweep hole w/ 20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP between 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KCl in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. x Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. x Use asphalt-type additives to further stabilize coal seams. x Increase fluid density as required to control running coals. x Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. H2S: DLBnot present in this hole section.H2S is n Page 51 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 29.0 Hilcorp Rig 169 Layout Page 52 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 30.0 FIT/LOT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 53 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 31.0 Choke Manifold Schematic Page 54 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 32.0 Casing Design Information Page 55 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 33.0 9-7/8” Hole Section MASP DLB Page 56 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 34.0 6-3/4” Hole Section MASP CRAIG ROSETTA J S004S015W Whiskey Gulch Pad North Fork Anchor R i v e r DADSCIRCOMICCIRHAVEN AVEOPPORTUNITY LNCAP E N I N I L C H I K A V EJODYS BLISS RDSEISMOGRAPHRDADL392666 ADL392666 WG#1_SHL WG#1_TPH WG#1_BHL UNIVERSITY OF ALASKA SCHLOESSER CRAIG KERIN LEO JOHN CRAIG ROSETTA J KERIN LEO JOHN KERIN BARBARA LEE CRAIG ROSETTA J STUTES STORMY C & ASSOC'S STUTES DOROTHY FLORENCE TRUST UNIVERSITY OF ALASKA ALASKA STATE D N R 4C1B LLC MCBRIDE DARCY JONES TERRY A SQUIRES-RODERICK SHANNA M PERRY JACK MCBRIDE DARCY 23 24 26 25 Whiskey Gulch #1 wp03 0 1,000 2,000 Feet Alaska State Plane Zone 4, NAD27 Legend WG#1_SHL WG#1_TPH WG#1_BHL Oil and Gas Unit Boundary Private Subsurface Mineral Leases ADNR Subsurface ADL Lease Number 392666 KPB Parcels (Surface) Map Date: 7/28/2021 Page 57 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 35.0 Spider Plot (Governmental Sections) Superseded Page 58 Version 2 July, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 2 36.0 Surface Plat (As-Built NAD27) !""# $ %!% %!% -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500True Vertical Depth (1500 usft/in)-2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 Vertical Section at 136.03° (1500 usft/in) WG#1 TD Tgt2 WG#1 T90 Tgt1 16" x 20" 10 3/4 x 13 1/2" 7 5/8" x 9 7/8" 4 1/2" x 6 3/4" 500 1 0 0 0 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 6 0 0 0 6 5 0 0 7 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 9 0 0 0 9 5 0 0 1 0 0 0 0 1 0 2 7 8 WG#1 wp03 Start Dir 3º/100' : 800' MD, 800'TVD End Dir : 1975.76' MD, 1902.89' TVD Start Dir 3º/100' : 6094.66' MD, 5265.6'TVD End Dir : 6905.48' MD, 6005.73' TVD Total Depth : 10277.98' MD, 9316.6' TVD Base Glacial Drift Beluga Tyonek Middle Tyonek Unconformity T-90 End Gas Prospectivity Hemlock Cretaceous Hilcorp Alaska, LLC Calculation Method:Minimum Curvature Error System:ISCWSA Scan Method: Closest Approach 3D Error Surface: Ellipsoid Separation Warning Method: Error Ratio WELL DETAILS: Plan: Whiskey Gulch 1 202.60 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 2128221.41 168391.78 59° 48' 48.150 N 151° 48' 5.366 W SURVEY PROGRAM Date: 2020-11-05T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 18.00 1500.00 WG#1 wp03 (WG#1) 3_MWD+AX+Sag 1500.00 7940.00 WG#1 wp03 (WG#1) 3_MWD+AX+Sag 7940.00 10277.98 WG#1 wp03 (WG#1) 3_MWD+AX+Sag FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 290.60 70.00 290.60 Base Glacial Drift 562.60 342.00 562.60 Beluga 1520.60 1300.00 1538.90 Tyonek 4093.60 3873.00 4659.11 Middle Tyonek Unconformity 5269.60 5049.00 6099.55 T-90 7020.60 6800.00 7939.24 End Gas Prospectivity 7520.60 7300.00 8448.55 Hemlock 8820.60 8600.00 9772.75 Cretaceous REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: Whiskey Gulch 1, True North Vertical (TVD) Reference:As-Built @ 220.60usft (169) Measured Depth Reference:As-Built @ 220.60usft (169) Calculation Method: Minimum Curvature Project:Seaview Prospect Site: Whiskey Gulch Well:Plan: Whiskey Gulch 1 Wellbore:WG#1 Design:WG#1 wp03 CASING DETAILS TVD TVDSS MD Size Name 120.00 -100.60 120.00 16 16" x 20" 1484.43 1263.83 1500.00 10-3/4 10 3/4 x 13 1/2" 7021.35 6800.75 7940.00 7-5/8 7 5/8" x 9 7/8" 9316.60 9096.00 10277.98 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 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 2 800.00 0.00 0.00 800.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 800' MD, 800'TVD 3 1975.76 35.27 136.64 1902.89 -254.92 240.74 3.00 136.64 350.61 End Dir : 1975.76' MD, 1902.89' TVD 4 6094.66 35.27 136.64 5265.60 -1984.22 1873.84 0.00 0.00 2729.02 WG#1 T90 Tgt1 Start Dir 3º/100' : 6094.66' MD, 5265.6'TVD 5 6905.48 10.97 133.51 6005.73 -2210.96 2093.85 3.00 -178.55 3044.96 End Dir : 6905.48' MD, 6005.73' TVD 6 10277.98 10.97 133.51 9316.60 -2652.83 2559.36 0.00 0.00 3686.17 WG#1 TD Tgt2 Total Depth : 10277.98' MD, 9316.6' TVD -3200 -2933 -2667 -2400 -2133 -1867 -1600 -1333 -1067 -800 -533 -267 0 267 533 South(-)/North(+) (400 usft/in)0 267 533 800 1067 1333 1600 1867 2133 2400 2667 West(-)/East(+) (400 usft/in) WG#1 T90 Tgt1 WG#1 TD Tgt2 16" x 20" 10 3/4 x 13 1/2" 7 5/8" x 9 7/8" 4 1/2" x 6 3/4" 250500750100 01250150017502000225025002750300032503500375040004250450047505000525055005750600062506500675070007250750077508000825085008750900092509317WG#1 wp03 Start Dir 3º/100' : 800' MD, 800'TVD End Dir : 1975.76' MD, 1902.89' TVD Start Dir 3º/100' : 6094.66' MD, 5265.6'TVD End Dir : 6905.48' MD, 6005.73' TVD Total Depth : 10277.98' MD, 9316.6' TVD Project: 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"!!!$2!""!< "! = "! + 7!>$ ""!!89";;!"!$"!9!"")9)85%)%2)!:)!%9$ 0.001.002.003.004.00Separation Factor550 1100 1650 2200 2750 3300 3850 4400 4950 5500 6050 6600 7150 7700 8250 8800 9350 9900 10450Measured Depth (1100 usft/in)WG#14 wp01No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS: Plan: Whiskey Gulch 1 NAD 1927 (NADCON CONUS) Alaska Zone 04202.60+N/-S+E/-W NorthingEastingLatitudeLongitude0.000.002128221.41 168391.7859° 48' 48.150 N151° 48' 5.366 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: Whiskey Gulch 1, True NorthVertical (TVD) Reference: As-Built @ 220.60usft (169)Measured Depth Reference:As-Built @ 220.60usft (169)Calculation Method:Minimum CurvatureCASING DETAILSTVD TVDSS MD Size Name120.00 -100.60 120.00 16 16" x 20"1484.43 1263.83 1500.00 10-3/4 10 3/4 x 13 1/2"7021.35 6800.75 7940.00 7-5/8 7 5/8" x 9 7/8"9316.60 9096.00 10277.98 4-1/2 4 1/2" x 6 3/4"SURVEY PROGRAMDate: 2020-11-05T00:00:00 Validated: Yes Version: Depth FromDepth ToSurvey/PlanTool18.00 1500.00 WG#1 wp03 (WG#1) 3_MWD+AX+Sag1500.00 7940.00 WG#1 wp03 (WG#1) 3_MWD+AX+Sag7940.00 10277.98 WG#1 wp03 (WG#1) 3_MWD+AX+Sag0.0040.0080.00120.00160.00200.00Centre to Centre Separation (80.00 usft/in)550 1100 1650 2200 2750 3300 3850 4400 4950 5500 6050 6600 7150 7700 8250 8800 9350 9900 10450Measured Depth (1100 usft/in)WG#14 wp01WG#15 wp01GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference18.00 To 10278.30Project: Seaview ProspectSite: Whiskey GulchWell: Plan: Whiskey Gulch 1Wellbore: WG#1Plan: WG#1 wp03Ladder/S.F. Plots WG#1_SHL Whiskey Gulch Pad SEC. 23 4S15W SCHLOESSER CRAIG KERIN LEO JOHN KERIN BARBARA LEE Source: Esri, Maxar, GeoEye, Earthstar Geographics, CNES/Airbus DS, USDA, USGS, AeroGRID, IGN, and the GIS User Community 151°48'0"W151°48'10"W151°48'20"W151°48'30"W 59°49'0"N59°49'0"N59°48'55"N59°48'55"N59°48'50"N59°48'50"N59°48'45"N59°48'45"N59°48'40"N59°48'40"N59°48'35"N59°48'35"NWhiskey Gulch #1 SHL - 660 ft Radius 0100200300400 Feet Legend Proposed WG#1_SHL WG #1 SHL - 660ft Radius Buffer Proposed Whiskey Gulch Pad KPB Parcels 1 inch = 200 feet Map Date: 6/10/2021 Document Path: O:\Alaska\GIS\cook_inlet\fields\WhiskeyGulch\mxds\WhiskeyGulch_#1_wp02a_660ft_Radius_v01.mxd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ig 147 and 169 Diverter Stackup 16'’ Hydril V 4.30' Hydril MSP 21-¼ 2M .50' 4.00' 2.67' 1.33' 4.37' Grade Level 3.09' DSA 16 ¾ 3M X 21 ¼ 2M 21 ¼ 2M Spool 21 ¼ 2M Diverter Tee 16'’ 150 outlet 4.08' 16'’ casing cut @ 64'’ below ground level .42' 1 Carlisle, Samantha J (CED) From:Frank Roach <Frank.Roach@hilcorp.com> Sent:Wednesday, June 16, 2021 9:25 AM To:McLellan, Bryan J (CED) Subject:RE: [EXTERNAL] Rig 169 pit capacity Bryan, Surfacepitcapacityon169is~800bbls.Activesystemisnormallybetween400Ͳ470bblsandtheremainingvolumeis heldinreservetoaddasneeded. Whenasourcewaterwellisnotavailableonlocation,wehavea400bbluprightthat’susedformixwatertobuild additionalmud. Regards, FrankVRoach DrillingEngineer 907.854.2321(c) 907.777.8413(o) From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Tuesday,June15,202117:40 To:FrankRoach<Frank.Roach@hilcorp.com> Subject:[EXTERNAL]Rig169pitcapacity Frank, What’sthepitcapacityonrig169andwhatvolumeofmud,relativetowellborecapacity,doyouplantokeepon location? Thanks BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 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. 1 Carlisle, Samantha J (CED) From:Frank Roach <Frank.Roach@hilcorp.com> Sent:Tuesday, June 29, 2021 3:53 PM To:McLellan, Bryan J (CED) Subject:RE: [EXTERNAL] Whiskey Gulch 1 PTD questions Attachments:Whiskey Gulch wp02 KICK_TOL 06-29-21.XLS; Whiskey Gulch 1 Dry-Hole Tree Configuration.pdf Bryan, ReceivedyouremailaboutbuttoninguptheWhiskeyGulchPTD.Pleaseseetheattached,dryͲholetreewellhead configurationandupdatedkicktolerance.Pertheupdateemail,we’llneedtoreach14.8ppgEMWwhileperformingthe LOTinordertoachieveaminimum15bblkicktolerance. Answerstoyourquestionsareinredandbelowtheirrespectivequestion. Withregardtotheadditionalfluidmonitoringforexplorationwells(thepreviousdiscussionsaround20AAC 25.033(f)(4)&(5)),wouldyouandJimReggbeavailabletomorrow(Wednesday)sometimeforaphoneconversation?I’m wantingtomakesureI’munderstandingtheregulationandnotoverthinkingthis. Thanksforthepermit/programquestionsandletmeknowifyouneedanythingadditional. Regards, FrankVRoach DrillingEngineer 907.854.2321(c) 907.777.8413(o) From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Thursday,June24,202118:04 To:FrankRoach<Frank.Roach@hilcorp.com> Subject:[EXTERNAL]WhiskeyGulch1PTDquestions Frank, I’vegotafewmorequestionsabouttheprogramforWhiskeyGulch1: 1. CanyoudoublecheckyourTailcementvolumeonthe7Ͳ5/8”casingcementjob.Ithinkthereisasmall discrepancy,butIcouldbewrong. Thetailvolumewascorrect.Thediscrepancywasinthewrittenoutequation.The“(7,933’Ͳ7,385’)”in theequationshouldread“(7,933’Ͳ7,433’)”todenotethe500’taillength.Programhasbeenupdatedto reflectthecorrectdepth. 2. What’sthedensityofthecompletionfluid? Plannedcompletionfluidis6%KCl.Densityof6%KClis8.65ppg 3. What’satempabandonmentcap?Itdoesnotseemtomatchtheproposedwellhead/treediagramattachedto theprogram.Ataminimum,I’dexpectatubingheadadaptorandonetreevalvenippledupforadryhole tree.Idon’tthinkI’dapproveonlyacapwithaneedlevalve. Agreed.“Tempabandonmentcap”isatermthatI’veonlyseensinceworkinghere.SinceI’vebeen workingtherig,wehaveeitherNUthetree(moreoftenthannot)oradryͲholetreeconfigurationifwe havecellarheightchallenges.Programandtemplatehavebeenupdatedtoreflectthis. 4. Sendanupdatedwellhead/treediagramifitisdifferentthantheoneinthePTD. DryͲholetreeconfigurationisattached. 2 5. OnyourMASPcalculationpagefor6Ͳ3/4”holesection,Idon’tthinkthesummaryiscorrect.Isn’tMASPgoingto begovernedbythelesserofthetwocalculations? Correct.Forthe6Ͳ3/4”holesection,MASPisgovernedbyporepressurewiththewellboreevacuatedto gas.Thecalculationpagehasbeenupdatedandreplacedintheprogram. BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 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. 1 Guhl, Meredith D (CED) From:Frank Roach <Frank.Roach@hilcorp.com> Sent:Thursday, July 29, 2021 11:02 AM To:Boyer, David L (CED); McLellan, Bryan J (CED) Cc:Roby, David S (CED); Davies, Stephen F (CED); Cody Terrell; Monty Myers; Benjamin Siks Subject:RE: [EXTERNAL] Changes in Whiskey Gulch No. 1 Well Trajectory (PTD 221-046) Attachments:Whiskey Gulch 1 Drilling Program Section 1 Update 7-29-21.pdf; WG 1 wp03 Spider Plot 7-29-21.pdf; MOC FORM Whiskey Gulch 1 Signed 7-29-21.pdf DavidandBryan, Attachedaretheupdatedsectionstothedrillingprogram: Section1.0(Page2):TopofProductiveHorizonhasbeenupdatedtoreflectthemarkerdepthreferencedinthespacing exemption.Thesevaluesarehighlightedingreen. Section35.0(Page57):SpiderMap,showingwellpath,surfaceholelocation,topofproductivehorizon,andTDhasbeen updated. TheMOChasalsobeenupdatedtoreflectthechangesandtheirlocationintheprogram. NOTE:Thechangefrompreliminarywellplantothefinalplanwiththe“asͲbuilt”surfacelocationdidshifttheX/Y coordinates(~2.05’east,2.39’south).However,thisshiftstayedwithintheexistinglandownernotification.No additionallandownersneedtobenotified. Letmeknowifyouneedanythingadditional. Regards, FrankVRoach DrillingEngineer 907.854.2321(c) 907.777.8413(o) From:CodyTerrell<cterrell@hilcorp.com> Sent:Wednesday,July28,202115:50 To:Boyer,DavidL(CED)<david.boyer2@alaska.gov> Cc:FrankRoach<Frank.Roach@hilcorp.com>;Roby,DavidS(CED)<dave.roby@alaska.gov>;McLellan,BryanJ(CED) <bryan.mclellan@alaska.gov>;Davies,StephenF(CED)<steve.davies@alaska.gov> Subject:RE:[EXTERNAL]ChangesinWhiskeyGulchNo.1WellTrajectory Hi David, After discussing with the team it looks like there was some miscommunication internally from the time the spacing exception was submitted to when the PTD was submitted. The target interval shown on the PTD should match what is on the spacing exception. Our drilling team informed me that they plan to submit an amendment to the PTD, if acceptable, showing the correct target interval, which will reflect what’s on the spacing exception. Also, there was a minor shift in surface hole location that shifted the well slightly North. This shift has no effect on the notice area and the impacted tracts. All landowners that should have been sent notice were notified. 2 Regards, Cody T. Terrell Landman Hilcorp Alaska, LLC Direct: 907-777-8432 Cell: 713-870-4532 From:Boyer,DavidL(CED)<david.boyer2@alaska.gov> Sent:Wednesday,July28,202111:19AM To:CodyTerrell<cterrell@hilcorp.com> Cc:FrankRoach<Frank.Roach@hilcorp.com>;Roby,DavidS(CED)<dave.roby@alaska.gov>;McLellan,BryanJ(CED) <bryan.mclellan@alaska.gov>;Davies,StephenF(CED)<steve.davies@alaska.gov> Subject:[EXTERNAL]ChangesinWhiskeyGulchNo.1WellTrajectory Importance:High HelloCody, WerecentlyreviewedaPTDandrevisedPTDfortheWhiskeyGulchNo.1well.Severalseniorstaffraisedconcernsover changesinthewelltrajectoryfromthatdescribedintheoriginalspacingexception.Fromthespacingexceptiontothe revisedPTD,thesurfacelocationmoved179’Nand42’Eandthetopofthetargetintervalmoved1976’Nand1852’W ofwhatwasapprovedinthespacingexception(CO790). OnthelandplatonP.57oftherevisedPTDpackage,theclosestprivatelandownershipwithin3000’forgas(and500’ foroil)occurstothesouthinSections26&25.DuetotheSHL,Target,andBHLchangesthatHilcorphasmadeto WhiskeyGulchNo.1sincethespacingexceptionwasissued,doanyadditionallandownersneedtobecontactedwho werenotpartoftheoriginal10listedinCO790(p.2)issuedon06/10/2021? Sincethespuddateforthewellison08/01/2021,pleasereplypromptlytothisconcern. Thankyou, DaveBoyer AOGCC 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. Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 221-046 N/A Mudlog and cuttings samples are required per 20 AAC 25.071(a). DLB 07/23/2021 Whiskey Gulch 1 X Whiskey Gulch Area Hilcorp Alaska, LLC X X WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:WHISKEY GULCH 1Initial Class/TypeEXP / 1-OILGeoArea820Unit50150On/Off ShoreOnProgramEXPField & PoolWell bore segAnnular DisposalPTD#:2210460NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberNo Exploration well.4 Well located in a defined poolNA No unit established at this time.5 Well located proper distance from drilling unit boundaryNA No other wells on this structure.6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes CO 790 already issued for spacing exception.11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes Kick tolerance is 25 bbls, assuming 14.8 ppg LOT achieved at surface casing.23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedYes27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes 5K BOP stack. Pressure test to 3500 psi. MPSP=316830 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)Yes H2S is not present in this hole section in the Anchor Point area.35 Permit can be issued w/o hydrogen sulfide measuresYes36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)Yes39 Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate6/21/2021ApprBJMDate7/2/2021ApprDLBDate6/21/2021AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:JLCDate6/30/2021Public CommissionerJMPDate6/30/2021 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 Monty M. Myers Drilling Manager Hilcorp Alaska, Inc. 3800 Centerpoint Drive, Suite 400 Anchorage, AK 99503 Re: Exploratory Field, Exploratory Pool, Whiskey Gulch 1 Hilcorp Alaska, LLC Permit to Drill Number: 221-046 Surface Location: 1548’ FSL, 1508’ FEL, Sec 23, T4S, R15W, SM, AK Bottomhole Location: 1047' FNL, 1022' FWL, Sec 25, T4S, R15W, SM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Conditions of approval: 1. Provide 24 hours’ notice for AOGCC to witness 4-1/2" liner pressure test and MITT and MITIA. 2. Minimum kick tolerance is 15 bbls assuming 0.5 ppg kick above actual mud weight. Requires 14.8 ppg LOT EMW minimum at 7-5/8" casing shoe assuming planned mud weight of 9.3 ppg. Actual kick tolerance to be verified by AOGCC after performing LOT at surface casing shoe. 3. BOP test to 3500 psi, annular test to 2500 psi, 7-day frequency. 4. Provide daily operations reports to AOGCC every day. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by Hilcorp Alaska, LLC in the attached application, the following well logs are also required for this well: Mudlog and cuttings samples are required per 20 AAC 25.071(a). Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Permit to Drill: 221-046 Page 2 of 2 Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of June, 2021. Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.30 14:57:34 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11.Well Name and Number: Bond No. 3. Address: 6.Proposed Depth: 12. Field/Pool(s): MD: 10,272' TVD: 9,317' 4a. Location of Well (Governmental Section): 7.Property Designation: Surface: Top of Productive Horizon: 8.DNR Approval Number: 13.Approximate Spud Date: Total Depth:9. Acres in Property:14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 221' 15. Distance to Nearest Well Open Surface: x-168401 y- 2128215 Zone-4 203' to Same Pool: N/A 16. Deviated wells: Kickoff depth: 800 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 35 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Cond 16" 84# X-56 Weld 120' Surface Surface 120' 120' 13-1/2" 10-3/4" 45.5# L-80 DWC/C 1,500' Surface Surface 1,500' 1,484' 9-7/8" 7-5/8" 29.7# L-80 USS-CDC 7,933' Surface Surface 7,933' 7,021' 6-3/4" 4-1/2" 12.6# L-80 DWC/C-HT 2,539' 7,733' 6,431' 10,272' 9,317' Tieback 4-1/2" 12.6# L-80 DWC/C-HT 7,733' Surface Surface 7,733' 6,431' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20.Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email: Contact Phone: Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Whiskey Gulch 1 Whiskey Gulch Prospect Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. Total Depth MD (ft): Total Depth TVD (ft): 022224484 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 L - 1895 ft3 / T - 171 ft3 3168 1548’ FSL, 1508’ FEL, Sec 23, T4S, R15W, SM, AK 1047' FNL, 1022' FWL, Sec 25, T4S, R15W, SM, AK N/A 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Hilcorp Alaska, LLC 1548’ FSL, 1508’ FEL, Sec 23, T4S, R15W, SM, AK ADL392666 2349 18. Casing Program: Top - Setting Depth - BottomSpecifications 4099 Cement Volume MDSize Plugs (measured): (including stage data) Driven L - 552 ft3 / T - 316 ft3 LengthCasing Conductor/Structural Effect. Depth MD (ft): Effect. Depth TVD (ft): Authorized Title: Authorized Signature: Production Liner Intermediate Authorized Name: Drilling Manager Monty Myers 7/15/2021 2411' to the lease line from SHL Frank Roach frank.roach@hilcorp.com 777-8413 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): L - 415 ft3 / T - 104 ft3 Tieback Assy. Stratigraphic Test No Mud log req'd: Yes No No Directional svy req'd: Yes No Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Single Well Gas Hydrates No Inclination-only svy req'd: Yes No Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal No No Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 6.10.2021 By Samantha Carlisle at 11:35 pm, Jun 10, 2021 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: 2021.06.10 16:17:43 -08'00' Monty M Myers X 221-046 X See additional conditions of approval on transmission letter. 50-231-20079-00-00 X DSR-6/11/21 X X (CO 790 06/10/2021) DLB 06/21/2021 Production from Whiskey Gulch No. 1 will commence only when an approved PA is in place. A copy of the decision and PA owners/landowners allocation schedule must be provided to AOGCC, prior to production. DLB X BJM 06/30/21 X JLC 6/30/21 6/30/21 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.30 14:58:02 -08'00' Whiskey Gulch #1 Drilling Program Confidential Exploration Tight Hole Rev 0 June 10, 2021 Contents 1.0 Well Summary ................................................................................................................................................ 2 2.0 Management of Change Information ........................................................................................................... 3 3.0 Tubular Program: .......................................................................................................................................... 4 4.0 Drill Pipe Information: .................................................................................................................................. 4 5.0 Internal Reporting Requirements ................................................................................................................. 5 6.0 Planned Wellbore Schematic ......................................................................................................................... 6 7.0 Drilling / Completion Summary .................................................................................................................... 7 8.0 Mandatory Regulatory Compliance / Notifications ..................................................................................... 9 9.0 R/U and Preparatory Work ......................................................................................................................... 11 10.0 N/U 21-1/4” Diverter .................................................................................................................................... 12 11.0 Drill 13-1/2” Hole Section ............................................................................................................................ 14 12.0 Run 10-3/4” Surface Casing ........................................................................................................................ 16 13.0 Cement 10-3/4” Surface Casing................................................................................................................... 19 14.0 BOP N/U and Test ........................................................................................................................................ 22 15.0 Drill 9-7/8” Hole Section .............................................................................................................................. 23 16.0 Run 7-5/8” Production Casing .................................................................................................................... 26 17.0 Cement 7-5/8” Production Casing ............................................................................................................... 29 18.0 Drill 6-3/4” Hole Section .............................................................................................................................. 32 19.0 Run 4-1/2” Production Liner ....................................................................................................................... 35 20.0 Cement 4-1/2” Production Liner ................................................................................................................. 38 21.0 4-1/2” Liner Tieback Polish Run and Cleanout Run................................................................................. 42 22.0 4-1/2” Tieback Run ...................................................................................................................................... 42 23.0 RDMO ........................................................................................................................................................... 43 24.0 BOP Schematic ............................................................................................................................................. 44 25.0 Wellhead Schematic ..................................................................................................................................... 45 26.0 Days Vs Depth ............................................................................................................................................... 46 27.0 Geo-Prog ....................................................................................................................................................... 47 28.0 Anticipated Drilling Hazards ...................................................................................................................... 48 29.0 Hilcorp Rig 169 Layout ................................................................................................................................ 51 30.0 FIT/LOT Procedure ..................................................................................................................................... 52 31.0 Choke Manifold Schematic .......................................................................................................................... 53 32.0 Casing Design Information .......................................................................................................................... 54 33.0 9-7/8” Hole Section MASP ........................................................................................................................... 55 34.0 6-3/4” Hole Section MASP ........................................................................................................................... 56 35.0 Spider Plot (Governmental Sections) .......................................................................................................... 57 36.0 Surface Plat (As-Staked NAD27) ................................................................................................................ 58 Page 2 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 1.0 Well Summary Well Whiskey Gulch #1 Pad & Old Well Designation Whiskey Gulch Pad / grass roots well Planned Completion Type 4-1/2” Production tubing with Gas Lift Target Reservoir(s) Beluga/Tyonek Gas Sands w/ appraisal leg Planned Well TD, MD / TVD 10,272’ MD / 9,317’ TVD PBTD, MD / TVD 10,192’ MD / 9,238’ TVD Surface Location (Governmental) 1547.5’ FSL, 1507.8’ FEL, Sec 23, T4S, R15W, SM, AK Surface Location (NAD 27) X=168401.60 Y=2128215.90 Top of Productive Horizon (Governmental) 1547.5’ FSL, 1507.8’ FEL, Sec 23, T4S, R15W, SM, AK TPH Location (NAD 27) X=168401.60, Y=2128215.90 BHL (Governmental) 1047’ FNL, 1022’ FWL, Sec 25, T4S, R15W, SM, AK BHL (NAD 27) X=170878.10, Y=2125500.00 AFE Number AFE Drilling Days 4 MOB, 53 DRLG AFE Completion Days 3 MOB, 7 COMP AFE Drilling Amount $6,949,031 AFE Completion Amount $894,698 Maximum Anticipated Pressure (Surface) 3168 psi Maximum Anticipated Pressure (Downhole/Reservoir) 4099 psi Work String 4-1/2” 16.6# S-135 CDS-40 RKB – GL 221.0’ (203 + 18) Ground Elevation 203.0’ BOP Equipment 11” 5M Annular BOP 11” 5M Double Ram 11” 5M Single Ram Page 3 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 2.0 Management of Change Information approved in advance by the AOGCC. SFD 6/21/2021 Page 4 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) Cond 16” 15.01” 14.822” - 84 X-56 Weld 2980 1410 - 13-1/2” 10-3/4” 9.950” 9.875” 11.750” 45.5 L-80 DWC/C 5210 2470 1040 9-7/8” 7-5/8” 6.875” 6.750” 8.500” 29.7 L-80 USS-CDC 6880 4790 683 6-3/4” 4-1/2” 3.958” 3.833” 5.000” 12.6 L-80 DWC/C-HT 8430 7500 288 4.0 Drill Pipe Information: Hole Section OD (in) ID (in) TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) All 4-1/2” 3.826 2.6875” 5.25” 16.6 S-135 CDS40 17,693 16,769 468k Cleanout 2-7/8” 2.323 2.265” 3.438” 7.9 P-110 PH-6 16,896 16,082 194k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 5 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry tab. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates x Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp.com, Frank.Roach@hilcorp.com, and cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting x Notify EHS field coordinator. 1. This could be one of (3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don’t wait until an emergency to have to call around and figure it out!!!! a. John Coston: O: (907) 777-6726 C: (907) 227-3189 b. Jacob Nordwall: O: (907) 777-8418 C: (907) 748-0753 2. Spills: Keegan Fleming: O:907-777-8477 C:907-350-9439 x Notify Drlg Manager 1. Monty M Myers: O: 907-777-8431 C: 907-538-1168 x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to mmyers@hilcorp.com, Frank.Roach@hilcorp.com, and cdinger@hilcorp.com 5.6 Casing and Cmt report x Send casing and cement report for each string of casing to mmyers@hilcorp.com, Frank.Roach@hilcorp.com, and cdinger@hilcorp.com Page 6 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 6.0 Planned Wellbore Schematic Page 7 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 7.0 Drilling / Completion Summary WHISKEY GULCH #1 is a slant directional wildcat exploration well to be drilled off of the Whiskey Gulch pad in Anchor Point. The well will be drilled to test the gas and oil potential of Beluga, Tyonek, Hemlock and Cretaceous sands. An exploratory leg will be drilled to test the entire potential hydrocarbon structure through the Cretaceous sections. The base plan is deviated wellbore with a kickoff point at ~800’ MD. Maximum hole angle will be 35 deg before dropping to 11 deg and TD of the well will be 10,272’ TMD/ 9,317’ TVD. Drilling operations are expected to commence approximately July 15th, 2021. The Hilcorp Rig # 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to ~1,500’ MD / 1,484’ TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 – 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal / beneficial reuse depending on test results. General sequence of operations: 1. MOB Hilcorp Rig # 169 to well site 2. N/U diverter and test. 3. Drill 13-1/2” hole to 1,500’ MD. 4. POOH w/drill pipe. Perform logging. Perform cleanout run. 5. Run and cement 10-3/4” surface casing. 6. ND diverter, N/U & test 11” x 5M BOP. 7. Drill 9-7/8” hole to 7,933’ MD. 8. POOH w/drill pipe. Perform logging. Perform cleanout run. 9. Run and cement 7-5/8” production casing. 10. Drill 6-3/4” hole section to 10,272’ MD. Perform wiper trips as needed. 11. POOH w/drill pipe. Perform logging and coring. Perform cleanout run. 12. Run and cmt 4-1/2” production liner. 13. POOH laying down running tools. 14. PU clean out assembly and RIH. Displace well to 6% KCL completion fluid. 15. POOH and LD clean out assembly. 16. Run tieback/upper completion 17. N/D BOP, N/U dry hole tree, RDMO. py If cmt returns to surface are not observed, a Temp log will be run between 6 – 18 hrs after CIP to determine TOC. Necessary remedial –,pg action will then be discussed with AOGCC authorities. l wildcat exploration well t Page 8 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 Reservoir Evaluation Plan: 1. Surface hole: GR + Res 2. Intermediate hole: Triple Combo w/e-line sonic after TD 3. Production Hole: Triple Combo w/e-line sonic and sidewall coring after TD 4. Mud loggers from surface casing point to TD. Page 9 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x BOPs shall be tested at (2) week intervals during the drilling of WHISKEY GULCH #1. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements” x Ensure AOGCC approved drilling permits are posted on the rig floor and in Co Man office. Regulation Variance Requests: x Hilcorp requests a variance to 20 AAC 25.035 (10)[B] requiring testing of the BOPE on a 7 day test cycle. Hilcorp feels that pressure testing the equipment on such a frequent basis causes undue stress and fatigue to secondary well control equipment that is not needed. Hilcorp requests the waiver for the 7 day test and would prefer to test on the 14 day cycle. Variance request is denied. bjm 7-day BOP test frequency for exploration wells. Page 10 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure (psi) 13-1/2” x 21-1/4” x 2M Hydril MSP diverter Function Test Only 9-7/8” & 6-3/4” x 11” x 5M Annular BOP x 11” x 5M Double Ram o Blind ram in btm cavity x Mud cross x 11” x 5M Single Ram x 3-1/8” 5M Choke Line x 2-1/16” x 5M Kill line x 3-1/8” x 2-1/16” 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/3500 (Annular 2500 psi) Subsequent Tests: 250/3500 (Annular 2500 psi) x Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). x Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to spud. x 24 hours notice prior to testing BOPs. x 24 hours notice prior to casing running & cement operations. x Any other notifications required in APD. Additional requirements may be stipulated on APD and Sundry. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email: jim.regg@alaska.gov Bryan McLellan / Petroleum Engineer / (O): 907-793-1226 / Email: bryan.mclellan@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 11 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 9.0 R/U and Preparatory Work 9.1 Set 16” conductor at +/-120’ below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install slip-on 16-3/4” 3M “A” section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Hilcorp Rig # 169, spot service company shacks, spot & R/U company man & toolpusher offices. 9.7 RU Mud loggers. Mud loggers are required on surface hole section taking 30’ samples 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 13-1/2” hole section. 9.10 Install 6” liners in mud pumps. x HHF-1000 mud pumps are rated at 2550 psi (85%) / 441 gpm (100%) at 120 spm with 6” liners. Page 12 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 10.0 N/U 21-1/4” Diverter 10.1 N/U 21-1/4” Diverter x N/U 21-1/4” diverter “T”. x Knife gate, 16” diverter line. x Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. Ensure to notify AOGCC inspector to witness function test of diverter. x NOTE: Ensure closing time on diverter annular is in line with API RP 64: o Annular element ID 20” or smaller: Less than 30 seconds o Annular element ID greater than 20”: Less than 45 seconds 10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the vent line tip. “Warning Zone” must include: x A prohibition on vehicle parking x A prohibition on ignition sources or running equipment x A prohibition on staged equipment or materials x Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set wear bushing in wellhead. Page 13 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 10.5 Rig 169 Orientation: Note: Actual layout may be different on location Page 14 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 11.0 Drill 13-1/2” Hole Section 11.1 P/U 13-1/2” directional drilling assy: x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Workstring will be 4.5” 16.6# S-135 CDS40 11.2 4-1/2” Workstring & HWDP will come from Hilcorp. 11.3 Begin drilling out from 16” conductor at reduced flow rates to avoid broaching the conductor. 11.4 Drill 13-1/2” hole section to 1,500’ MD/ 1,484’ TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. x Utilize past experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. x Keep swab and surge pressures low when tripping. x Make wiper trips every 500’ or every couple days unless hole conditions dictate otherwise. x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. x TD the hole section in a good shale between 1,400’ and 1,600’MD. x Take MWD surveys every stand drilled (60’ intervals). 11.5 13-1/2” hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8 – 9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 120-1500’ 8.8 – 9.5 85-150 20 - 40 25 - 45 <10 8.5-9.0 Note: 8.46 ppg EMW needed. DLB y()pp W spud mud at 8.8 ppg. 8.8 – 9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud– Page 15 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 System Formulation: Aquagel + FW spud mud Product Concentration FRESH WATER SODA ASH AQUAGEL CAUSTIC SODA BARAZAN D+ BAROID 41 PAC-L /DEXTRID LT ALDACIDE G X-TEND II 0.905 bbl 0.5 ppb 12-15 ppb 0.1 ppb (9 pH) as needed as required for weight if required for <12 FL 0.1 ppb 0.02 ppb 11.6 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16” conductor shoe. 11.7 TOH with the drilling assy, handle BHA as appropriate. 15.1 RU E-Line and perform wireline logging plan. 11.8 PU 13-1/2” cleanout assembly and RIH to TD, noting any tight spots along the way. CBU at least once at TD to ensure hole is clean for casing run. POOH and LD cleanout assembly. Page 16 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 12.0 Run 10-3/4” Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 10-3/4” casing running equipment. x Ensure 10-3/4” DWC x CDS 40 XO on rig floor and M/U to FOSV. x R/U fill-up line to fill casing while running. x Ensure all casing has been drifted on the location prior to running. x Be sure to count the total # of joints on the location before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 12.3 P/U shoe joint. Visually verify no debris inside joint. 12.4 Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ float shoe bucked on (thread locked). x (1) Joint with coupling thread locked. x (1) Joint with float collar bucked on pin end & thread locked. x Install (2) centralizers on shoe joint over a stop collar. 10’ from each end. x Install (1) centralizer, mid tube on thread locked joint and on FC joint. x Ensure proper operation of float equipment. 12.5 Continue running 10-3/4” surface casing x Fill casing while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x Install (1) centralizer every other joint to 300’. Do not run any centralizers above 300’ in the event a top out job is needed. x Utilize a collar clamp until weight is sufficient to keep slips set properly. 10-3/4” 45.5# DWC/C M/U torques Casing OD Minimum Maximum Yield Torque 10-3/4” 35,900 ft-lbs 42,200 ft-lbs 48,500 ft-lbs pppyp Install (1) centralizer every other joint to 300’. Do not run any centralizers above 300’ in the () y event a top out job is needed. Page 17 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 Page 18 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 19 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 13.0 Cement 10-3/4” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface. x Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 30 bbls of 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume + 50% open hole excess. Job will consist of lead & tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 16” Conductor x 10-3/4” casing annulus: 120’ x .10660 bpf = 12.79 71.8 12.0 ppg LEAD: 13-1/2” OH x 10-3/4” Casing annulus: (1000’ – 120’) x .06478 bpf x 1.5 = 85.51 480.1 Total LEAD: 98.31 bbl 551.9 ft3 15.4 ppg TAIL: 13-1/2” OH x 10-3/4” Casing annulus: (1500’- 1000’) x .06478 bpf x 1.5 = 48.59 272.8 15.4 ppg TAIL: 10-3/4” Shoe track: 80 x .09617 bpf = 7.69 43.2 Total TAIL: 56.28 bbl 316.0 ft3 TOTAL CEMENT VOL: 154.59 bbl 867.9 ft3 Verified cement calcs - bjm Page 20 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 Cement Slurry Design: 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets “sticky”, land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 1500’- 80’ = 1420’ x .09617 bpf = 137 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.13 Do not overdisplace by more than ½ shoe track volume. Total volume in shoe track is 7.7 bbls. x Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12 – 18 hours after CIP. x Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5”. 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. Lead Slurry (1000’ MD to surface) Tail Slurry (1500’ to 1000’ MD) System Extended Conventional Density 12 lb/gal 15.8 lb/gal Yield 2.40 ft3/sk 1.16 ft3/sk Mixed Water 14.25 gal/sk 5.04 gal/sk Mixed Fluid 14.25 gal/sk 5.04 gal/sk Page 21 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to cdinger@hilcorp.com and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 22 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 14.0 BOP N/U and Test 14.1 ND Diverter line and diverter 14.2 N/U multi-bowl wellhead assy. Install 10-3/4” packoff P-seals. Test to 3000 psi. 14.3 N/U 11” x 5M BOP as follows: x BOP configuration from Top down: 11” x 5M annular BOP/11” x 5M double ram /11” x 5M mud cross/11” x 5M single ram x Double ram should be dressed with 2-7/8” x 5” variable bore rams in top cavity, blind ram in btm cavity. x Single ram should be dressed with 2-7/8” x 5” variable bore rams x N/U bell nipple, install flowline. x Install (2) manual valves & a check valve on kill side of mud cross. x Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2” BOP test assy, land out test plug (if not installed previously). x Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. x Ensure to leave “B” section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.0 ppg 6% KCL PHPA mud system. 14.8 R/U mud loggers for production hole section. 14.9 Rack back as much 4-1/2” DP in derrick as possible to be used while drilling the hole section. 14.10 Install 5-1/2” liners in mud pumps. x HHF-1000 mud pumps are rated at 3036 psi (85%) / 370 gpm (100%) at 120 spm with 5-1/2” liners. x 9.0 ppg 6% KCL PHPA mud system. Page 23 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 15.0 Drill 9-7/8” Hole Section 15.2 Pull test plug, run and set wear bushing 15.3 Ensure BHA components have been inspected previously. 15.4 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.5 TIH, Conduct shallow hole test of MWD and confirm all LWD functioning properly. 15.6 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.7 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.8 Workstring will be 4.5” 16.6# S-135 CDS40. Ensure to have enough 4-1/2” DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 15.9 9-7/8” hole section mud program summary: Weighting material to be used for the hole section will be barite, salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: MD Mud Weight Viscosity Plastic Viscosity Yield Point pH HPHT 1,500’- 7,933’ 9.0 – 10.0 40-53 15-25 15-25 8.5-9.5 11.0 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Note: 8.46 ppg EMW needed. DLB Page 24 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water KCl Caustic BARAZAN D+ EZ MUD DP DEXTRID LT PAC-L BARACARB 5/25/50 BAROID 41 ALDACIDE G BARACOR 700 BARASCAV D 0.905 bbl 22 ppb (29 K chlorides) 0.2 ppb (9 pH) 1.25 ppb (as required 18 YP) 0.75 ppb (initially 0.25 ppb) 1-2 ppb 1 ppb 15 - 20 ppb (5 ppb of each) as required for a 9.0 – 10.0 ppg 0.1 ppb 1 ppb 0.5 ppb (maintain per dilution rate) 15.10 TIH w/ 9-7/8” directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.11 R/U and test casing to 3000 psi / 30 min. Ensure to record volume / pressure and plot on LOT graph. AOGCC requirement is 50% of burst. 10-3/4” burst is 5210 psi / 2 = 2605 psi. 15.12 Drill out shoe track and 20’ of new formation. 15.13 CBU and condition mud for LOT. 15.14 Conduct LOT. Target value is 13.9 ppg EMW. Note: Offset field test data predicts frac gradient at the 10-3/4” shoe to be between 12.5 – 15.5 ppg EMW. A 13.9 ppg LOT results in a 4.6 ppg kick margin and a >10 bbl kick tolerance volume while drilling with the planned MW of 9.5 ppg. Kick tolerance = (13.9-9.3)X(1484/7021) = 0.97 15.15 Drill 9-7/8” hole section to 7,933’ MD / 7,021’ TVD x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at 500 - 600 gpm. Ensure shaker screens are set up to handle this flowrate. x Keep swab and surge pressures low when tripping. x Make wiper trips every 1000’ unless hole conditions dictate otherwise. x On the third wiper trip (around 4,500’ MD), trip back to the 10-3/4” shoe to split the hole section in half x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. x Take MWD surveys every 100’ drilled. Surveys can be taken more frequently if deemed necessary. x Take (3) sets of formation samples every 20’. AOGCC does not use this calculation in determining kick tolerance. Kick tolerance with 13.9 ppg LOT EMW provides 10.1 bbl kick tolerarance, which is not enough. A 15 bbl minimum KT is required, so minimum of 14.8 ppg LOT EMW is required to drill the well as designed.-bjm Conduct LOT. gpp AOGCC requirement is 50% of burst. Page 25 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 10-3/4” shoe. 15.17 TOH with the drilling assy, standing back drill pipe. 15.18 LD BHA 15.19 RU E-Line and perform wireline logging plan. 15.20 RD E-Line. PU 9-7/8” clean out BHA, and TIH to TD. 15.21 Pump sweep, CBU and condition mud for casing run. 15.22 POOH and LD BHA 15.23 Install 7-5/8” casing rams in BOP stack and test. Install 7-5/8” casing rams in BOP stack and test. Ensure MW in = MW out before TOH Page 26 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 16.0 Run 7-5/8” Production Casing 16.1. R/U Weatherford 7-5/8” casing running equipment. x Ensure 7-5/8” CDC x CDS 40 crossover on rig floor and M/U to FOSV. x R/U fill up line to fill casing while running. x Ensure all casing has been drifted prior to running. x Be sure to count the total # of joints before running. x Keep hole covered while R/U equipment. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). x (1) joint casing, threadlocked (coupling also thread locked) x (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). x Solid body centralizers will be pre-installed on shoe joint an FC joint. x Leave centralizers free floating so that they can slide up and down the joint. x Ensure proper operation of float shoe and float collar. x Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 7-5/8” production casing x Fill casing while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x Install solid body centralizers on every joint across zones of interest, TBD after LWD. x Install solid body centralizers on every other joint to 10-3/4” shoe. Leave the centralizers free floating. x Pick up swell packer and place in string at approximately 250’ above 10-3/4” surface casing shoe depth (~1,250’ MD). 16.5. Continue running 7-5/8” production casing 7-5/8” 29.7# CDC M/U torques Casing OD Minimum Maximum Yield Torque 7-5/8” 14,000 ft-lbs 17,000 ft-lbs 20,900 ft-lbs () p ( p g Solid body centralizers will be pre-installed on shoe joint an FC joint. pppyp Install solid body centralizers on every joint across zones of interest, Install solid body centralizers on every other joint to 10-3/4” shoe. yyj Page 27 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 Page 28 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 16.6. Run in hole w/ 7-5/8” casing to the 10-3/4” casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight, and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/ casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. 16.12. Monitor PUW & SOW. Circulate BU if needed. Highlight zones of interest before running past, ex: coals 16.13. Swedge up and wash last stand before picking up hanger/landing joint. Note slack-off and pick- up weights. 16.14. P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 16.15. Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 16.16. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low-end rheology of the drilling fluid by adding water and thinners. 16.17. Rotate and reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 29 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 17.0 Cement 7-5/8” Production Casing 17.1. Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. x Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. x Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations until hole gets sticky. 17.3. R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 17.4. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.5. Test surface cmt lines to 4500 psi. 17.6. Pump remaining 30 bbls 12.5 ppg Mud Push spacer. 17.7. Drop bottom plug. Mix and pump cmt per below recipe. 17.8. Cement volume based on annular volume + 40% open hole excess. Job will consist of lead & tail, TOC brought to 500’ above surface casing shoe. Page 30 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 Estimated Total Cement Volume: Cement Slurry Design: 17.9. Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets “sticky”, land the hanger on seat and continue with the cement job. 17.10. After pumping cement, drop top plug and displace cement with mud. Displace at max rate of 5 bbl/min. 17.11. Displacement calculation: 7933’- 80’ = 7853’ x .04592 bpf = 361 bbls 17.12. If hole conditions allow – continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 10-3/4” casing x 7-5/8” casing annulus: (1500’ – 1000’) x .03969 bpf = 19.85 111.4 12.0 ppg LEAD: 9-7/8” OH x 7-5/8” Casing annulus: (7433’ – 1500’) x .03825 bpf x 1.4 = 317.72 1783.8 Total LEAD: 337.56 bbl 1895.3 ft3 15.4 ppg TAIL: 9-7/8” OH x 7-5/8” Casing annulus: (7933’- 7385’) x .03825 bpf x 1.4 = 26.78 150.3 15.4 ppg TAIL: 7-5/8” Shoe track: 80 x .04592 bpf = 3.67 20.6 Total TAIL: 30.45 bbl 171.0 ft3 TOTAL CEMENT VOL: 368.01 bbl 2066.2 ft3 Lead Slurry (7433’ MD to 1000’ MD) Tail Slurry (7933’ to 7433’ MD) System Extended Conventional Density 12 lb/gal 15.3 lb/gal Yield 2.4 ft3/sk 1.24 ft3/sk Mixed Water 14.09 gal/sk 5.58 gal/sk Mixed Fluid 14.09 gal/sk 5.58 gal/sk 7433' bjm Page 31 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 17.13. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.14. Do not overdisplace by more than ½ shoe track. Shoe track volume is 3.7 bbls. 17.15. Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. Note amount of fluid returned after bumping plug and releasing pressure. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 17.16. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.17. R/D cement equipment. Flush out wellhead with FW. 17.18. Back out and L/D landing joint. Flush out wellhead with FW. 17.19. M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 17.20. Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job. If intermittent, note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to cdinger@hilcorp.com and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 32 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 18.0 Drill 6-3/4” Hole Section 15.24 Pull test plug, run and set wear bushing 15.25 Ensure BHA components have been inspected previously. 15.26 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.27 TIH, Conduct shallow hole test of MWD and confirm all LWD functioning properly. 15.28 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.29 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.30 Workstring will be 4-1/2” 16.6# S-135 CDS40. Ensure to have enough 4-1/2” DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. 15.31 6-3/4” hole section mud program summary: Weighting material to be used for the hole section will be barite, salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Properties: MD Mud Weight Viscosity Plastic Viscosity Yield Point pH HPHT 7,933’- 10,272’ 9.0 – 10.0 40-53 15-25 15-25 8.5-9.5 11.0 Note: 8.46 ppg EMW minimum needed. DLB Replace casing rams with VBRs and test. bjm 9.0 ppg 6% KCL PHPA fresh water based drilling fluid. Page 33 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water KCl Caustic BARAZAN D+ EZ MUD DP DEXTRID LT PAC-L BARACARB 5/25/50 BAROID 41 ALDACIDE G BARACOR 700 BARASCAV D 0.905 bbl 22 ppb (29 K chlorides) 0.2 ppb (9 pH) 1.25 ppb (as required 18 YP) 0.75 ppb (initially 0.25 ppb) 1-2 ppb 1 ppb 15 - 20 ppb (5 ppb of each) as required for a 9.0 – 10.0 ppg 0.1 ppb 1 ppb 0.5 ppb (maintain per dilution rate) 15.32 TIH w/ 6-3/4” directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.33 R/U and test casing to 3500 psi / 30 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC requirement is 50% of burst. 7-5/8” burst is 6890 psi / 2 = 3445 psi. 15.34 Drill out shoe track and 20’ of new formation. 15.35 CBU and condition mud for LOT. 15.36 Conduct LOT. Target value is 13.5 ppg EMW. Note: Offset field test data predicts frac gradient at the 7-5/8” shoe to be between 12.5 – 15.5 ppg EMW. A 13.5 ppg LOT results in a 4.5 ppg kick margin and a >10 bbl kick tolerance volume while drilling with the planned MW of 9.5 ppg. Kick tolerance = (13.5-9.5)X(7021/9317) = 3.01 15.37 Drill 6-3/4” hole section to 10,272’ MD / 9,317’ TVD x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Pump at 400 - 500 gpm. Ensure shaker screens are set up to handle this flowrate. x Keep swab and surge pressures low when tripping. x Make wiper trips every 1000’ unless hole conditions dictate otherwise. x Ensure shale shakers are functioning properly. Check for holes in screens on connections. x Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. x Take MWD surveys every 100’ drilled. Surveys can be taken more frequently if deemed necessary. x Take (3) sets of formation samples every 20’. 15.38 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8” shoe. Confirm MW in = MW out before TOH. ppg ppg e drilling with the planned MW of 9.5 ppg. Page 34 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 15.39 TOH with the drilling assy, standing back drill pipe. 15.40 LD BHA 15.41 RU E-Line and perform wireline logging plan. 15.42 RD E-Line. PU 6-3/4” clean out BHA, and TIH to TD. 15.43 Pump sweep, CBU and condition mud for casing run. 15.44 POOH and LD BHA 15.45 2-7/8” x 5-1/2” VBRs previously installed in BOP stack and tested with 4-1/2” test joint. Confirm MW in = MW out before TOH. 2-7/8” x 5-1/2” VBRs previously installed in BOP stack and tested with 4-1/2” test j .joint. Page 35 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 19.0 Run 4-1/2” Production Liner 16.6. R/U Weatherford 4-1/2” casing running equipment. x Ensure 4-1/2” DWC/C-HT x CDS 40 crossover on rig floor and M/U to FOSV. x R/U fill up line to fill liner while running. x Ensure all liner has been drifted prior to running. x Be sure to count the total # of joints before running. x Keep hole covered while R/U liner tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 16.7. P/U shoe joint, visually verify no debris inside joint. 16.8. Continue M/U & thread locking shoe track assy consisting of: x (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked). x (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked). x (1) Joint with Baker landing collar bucked on pin end & threadlocked. x Solid body centralizers will be pre-installed on shoe joint an FC joint. x Leave centralizers free floating so that they can slide up and down the joint. x Ensure proper operation of float shoe and float collar. x Utilize a collar clamp until weight is sufficient to keep slips set properly 16.9. Continue running 4-1/2” production liner x Fill liner while running using fill up line on rig floor. x Use “API Modified” thread compound. Dope pin end only w/ paint brush. x Install solid body centralizers on every joint across zones of interest, TBD after LWD. x Install solid body centralizers on every other joint to 7-5/8” shoe. Leave the centralizers free floating. 16.10. Continue running 4-1/2” production liner 4-1/2” 12.6# DWC/C-HT M/U torques Casing OD Minimum Maximum Yield Torque 4-1/2” 5,800 ft-lbs 6,500 ft-lbs 9,240 ft-lbs pppyp Install solid body centralizers on every joint across zones of interest Install solid body centralizers on every other joint to 7-5/8” shoe. yyj () g p Solid body centralizers will be pre-installed on shoe joint an FC joint. Page 36 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 Page 37 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 16.18. Run in hole w/ 4-1/2” liner to the 7-5/8” casing shoe. 16.19. Fill the liner with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 16.20. Obtain slack off weight, PU weight, rotating weight, and torque of the liner. 16.21. Circulate 2X bottoms up at shoe, ease liner thru shoe. 16.22. Continue to RIH w/ liner no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.23. Set liner slowly in and out of slips. 16.24. PU 4-1/2” X 7-5/8” Baker liner hanger/LTP assembly. RIH 1 stand and circulate one liner volume to clear string. Obtain slack off weight, PU weight, rotating weight, and torque parameters of the liner. 16.25. Continue running in hole at slow speeds to avoid surging well. Target 20 ft/min and adjust slower as hole conditions dictate. 16.26. Monitor PUW & SOW. Circulate BU if needed. Highlight zones of interest before running past, ex: coals 16.27. Swedge up and wash last stand to bottom. P/U 2-5’ off bottom. Note slack-off and pick-up weights. 16.28. Stage pump rates up slowly to circulating rate. Circ and condition mud with liner on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low-end rheology of the drilling fluid by adding water and thinners. 16.29. Rotate and reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 38 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 20.0 Cement 4-1/2” Production Liner 17.21. Hold a pre-job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. x Pump 20 bbls of freshwater through all of Halliburton’s equipment, taking returns to cuttings bin, prior to pumping any fluid downhole x How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. x Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. x Positions and expectations of personnel involved with the cmt operation. x Document efficiency of all possible displacement pumps prior to cement job. 17.22. Attempt to rotate and reciprocate the liner during cmt operations until hole gets sticky 17.23. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.24. Test surface cmt lines to 4500 psi. 17.25. Pump remaining 30 bbls 12.5 ppg Mud Push spacer. 17.26. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 40% OH excess. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 7-5/8” csg x 4-1/2” drillpipe annulus: 200’ x .02624 bpf = 5.25 29.5 12.0 ppg LEAD: 7-5/8” csg x 4-1/2” liner annulus: 200’ x .02624 bpf = 5.25 29.5 12.0 ppg LEAD: 6-3/4” OH x 4-1/2” annulus: (9772’ – 7933’) x .02459 bpf x 1.4 = 63.31 355.5 Total LEAD: 73.81 bbl 414.4 ft3 15.4 ppg TAIL: 6-3/4” OH x 4-1/2” annulus: (10272’- 9772’) x .02459 bpf x 1.4 = 17.21 96.6 15.4 ppg TAIL: 4-1/2” Shoe track: 80 x .01522 bpf = 1.22 6.8 Total TAIL: 18.43 bbl 103.5 ft3 TOTAL CEMENT VOL: 92.24 bbl 517.9 ft3 p 40% OH excess. Verified cement calcs bjm Page 39 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 Cement Slurry Design: 17.27. Drop drillpipe dart and displace with drilling mud. If hole conditions allow – continue rotating and reciprocating liner throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.28. Displace cement at max rate of 5 bbl/min. Reduce pump rate to 2-3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point. 17.29. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.30. Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger (ensure pressure is above nominal setting pressure, but below pusher tool activation pressure). Hold pressure for 3-5 minutes. 17.31. Slack off total liner weight plus 30k to confirm hanger is set. 17.32. Do not overdisplace by more than ½ shoe track. Shoe track volume is 1.2 bbls. 17.33. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.34. Pick up to expose dogs and set liner top packer. 17.35. Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS nipple. Bump up pressure as req’d to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack-off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 17.36. Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. Lead Slurry (9772’ MD to 7733’ MD) Tail Slurry (10272’ to 9772’ MD) System Extended Conventional Density 12 lb/gal 15.3 lb/gal Yield 2.4 ft3/sk 1.24 ft3/sk Mixed Water 14.09 gal/sk 5.58 gal/sk Mixed Fluid 14.09 gal/sk 5.58 gal/sk Page 40 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 17.37. Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 17.38. RD cementers and flush equipment. POOH, LDDP and running tool. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 17.39. If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 17.40. NOTE: Some hole conditions may require movement of the drillpipe to “work” the torque down to the setting tool. 17.41. After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. 17.42. WOC minimum of 12 hours, test liner to 3500 psi and chart for 30 minutes. Page 41 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if liner is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job. If intermittent, note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” liner tally & liner and cement report to cdinger@hilcorp.com and Frank.Roach@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 42 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 21.0 4-1/2” Liner Tieback Polish Run and Cleanout Run 18.1. PU liner tieback polish mill assy per Baker rep and RIH on drillpipe. 18.2. RIH to top of liner assembly and establish parameters. Polish tieback receptacle per Baker procedure. 18.3. POOH, and LD polish mill. 18.4. M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. x 3-1/2” bit or mill x Casing scraper & brush for 4-1/2” 12.6# tubulars x +/- 5100’ 2-7/8” PH-6 workstring. x Casing scraper & brush for 7-5/8” 29.7# casing x 4-1/2” DP to surface. 18.5. TIH & clean out well to landing collar (+/- 6,250’ MD). x Circulate as needed on trip in if string begins to take weight. x Circulate hi-vis sweeps as necessary to carry debris out of wellbore. x Ensure 3-1/2” bit is worked down to the landing collar. x Space out the cleanout BHA so that the 3-1/2” bit reaches the 4-1/2” landing collar when crossover/7-5/8” casing scraper is +/- 30’ above the 4-1/2” liner top. 18.6. After wellbore has been cleaned out satisfactorily using mud, test casing/liner envelope to 3500 psi / 30 min. Ensure to chart record casing test. 18.7. Displace drilling fluid in wellbore with a hi-vis pill followed by 6% KCl completion fluid. 18.8. POOH, LDDP and workstring. Clean and clear rig floor in preparation for running tieback. 22.0 4-1/2” Tieback Run 19.1 PU 4-1/2” tieback assembly and RIH with 4-1/2” 17# L-80 CDC HTQ casing. 19.2 No-go tieback seal assembly in liner PBR and mark pipe. PU pup joint(s) if necessary to space out tieback seals in PBR. 19.3 PU hanger and land string in hanger bowl. Note distance of seals from no-go. 19.4 Install packoff and test hanger void. Provide 24 hrs notice to AOGCC to witness test. Displace drilling fluid in wellbore with a hi-vis pill followed by 6% KCl completion fluid. 8.65 ppg fluid Page 43 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 19.5 Test 4-1/2” liner and tieback to 3,500 psi and chart for 30 minutes. 19.6 Test 7-5/8” x 4-1/2” annulus to 2,500 psi and chart for 30 minutes. 23.0 RDMO 20.1 Install BPV in wellhead 20.2 N/D BOPE 20.3 N/U temp abandonment cap 20.4 RDMO Hilcorp Rig #169 N/U temp abandonment cap Provide 24 hrs notice to AOGCC to witness MITIA and MITT. Sundry required for perforating. Does not match wellhead/tree diagram attached. Need at least one tree valve installed as a dry hole tree. Updated diagram with dry hole tree is attached. Page 44 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 24.0 BOP Schematic Page 45 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 25.0 Wellhead Schematic Superseded with dry-hole tree, but this complete tree configuration is allowed under this PTD if Hilcorp decides to install it. Page 46 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 26.0 Days Vs Depth Page 47 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 27.0 Geo-Prog Page 48 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 28.0 Anticipated Drilling Hazards 13-1/2” Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP between 25 – 45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of ~50 - ~60 lbs/100ft2 to combat this issue. Maintain low flow rates for the initial 200’ of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 – 30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. DLB H2S: H2S is not present in this hole section. Page 49 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 9-7/8” Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Given the volume of losses experienced in KU 42-12 when drilling through Pool 6, ensure all LCM inventory is fully stocked before drilling out surface casing. Hole Cleaning: Maintain rheology w/ viscosifier as necessary. Sweep hole w/ 20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP between 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KCl in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. x Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. x Use asphalt-type additives to further stabilize coal seams. x Increase fluid density as required to control running coals. x Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. DLB H2S: H2S is not present in this hole section. Page 50 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 6-3/4” Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Given the volume of losses experienced in KU 42-12 when drilling through Pool 6, ensure all LCM inventory is fully stocked before drilling out surface casing. Hole Cleaning: Maintain rheology w/ viscosifier as necessary. Sweep hole w/ 20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP between 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KCl in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. x Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. x Use asphalt-type additives to further stabilize coal seams. x Increase fluid density as required to control running coals. x Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. H2S: not present in this hole section. H2S is n DLB Page 51 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 29.0 Hilcorp Rig 169 Layout Page 52 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 30.0 FIT/LOT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 53 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 31.0 Choke Manifold Schematic Page 54 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 32.0 Casing Design Information Page 55 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 33.0 9-7/8” Hole Section MASP Page 56 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 34.0 6-3/4” Hole Section MASP is governed by max pore pressure minus full column of gas at 0.1 psi/ft - bjm Page 57 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 35.0 Spider Plot (Governmental Sections) Page 58 Version 0 June, 2021 WHISKEY GULCH #1 Drilling Procedure Rev 0 36.0 Surface Plat (As-Staked NAD27) ! " #$# %#$# -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500True Vertical Depth (1500 usft/in)-2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 Vertical Section at 136.08° (1500 usft/in) WG#1 TD Tgt2 WG#1 T90 Tgt1 16" x 20" 10 3/4 x 13 1/2" 7 5/8" x 9 7/8" 4 1/2" x 6 3/4" 500 1 0 0 0 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 6 0 0 0 6 5 0 0 7 0 0 0 7 5 0 0 8 0 0 0 8 5 0 0 9 0 0 0 9 5 0 0 1 0 0 0 0 1 0 2 7 2 WG#1 wp02a Start Dir 3º/100' : 800' MD, 800'TVD End Dir : 1971.62' MD, 1899.5' TVD Start Dir 3º/100' : 6088.84' MD, 5266'TVD End Dir : 6894.61' MD, 6001.85' TVD Total Depth : 10271.81' MD, 9317' TVD Base Glacial Drift Beluga Tyonek Middle Tyonek Unconformity T-90 End Gas Prospectivity Hemlock Cretaceous 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: Prelim: Whiskey Gulch 1 203.00 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 2128215.90 168401.60 59° 48' 48.098 N 151° 48' 5.172 W SURVEY PROGRAM Date: 2020-11-05T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 18.00 1500.00 WG#1 wp02a (WG#1) 3_MWD+AX+Sag 1500.00 7932.00 WG#1 wp02a (WG#1) 3_MWD+AX+Sag 7932.00 10271.81 WG#1 wp02a (WG#1) 3_MWD+AX+Sag FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 291.00 70.00 291.00 Base Glacial Drift 563.00 342.00 563.00 Beluga 1521.00 1300.00 1539.33 Tyonek 4094.00 3873.00 4655.49 Middle Tyonek Unconformity 5270.00 5049.00 6093.73 T-90 7021.00 6800.00 7932.83 End Gas Prospectivity 7521.00 7300.00 8442.19 Hemlock 8821.00 8600.00 9766.52 Cretaceous REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Prelim: Whiskey Gulch 1, True North Vertical (TVD) Reference:WG#1 As-staked RKB @ 221.00usft Measured Depth Reference:WG#1 As-staked RKB @ 221.00usft Calculation Method:Minimum Curvature Project:Seaview Prospect Site:Whiskey Gulch Well:Prelim: Whiskey Gulch 1 Wellbore:WG#1 Design:WG#1 wp02a CASING DETAILS TVD TVDSS MD Size Name 120.00 -101.00 120.00 16 16" x 20" 1484.43 1263.43 1500.00 10-3/4 10 3/4 x 13 1/2" 7021.00 6800.00 7932.83 7-5/8 7 5/8" x 9 7/8" 9317.00 9096.00 10271.81 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 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 2 800.00 0.00 0.00 800.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 800' MD, 800'TVD 3 1971.62 35.15 136.72 1899.50 -253.51 238.76 3.00 136.72 348.22 End Dir : 1971.62' MD, 1899.5' TVD 4 6088.84 35.15 136.72 5266.00 -1978.98 1863.87 0.00 0.00 2718.36 WG#1 T90 Tgt1 Start Dir 3º/100' : 6088.84' MD, 5266'TVD 5 6894.61 11.00 133.49 6001.85 -2204.08 2081.91 3.00 -178.50 3031.74 End Dir : 6894.61' MD, 6001.85' TVD 6 10271.81 11.00 133.49 9317.00 -2647.59 2549.40 0.00 0.00 3675.48 WG#1 TD Tgt2 Total Depth : 10271.81' MD, 9317' TVD -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 South(-)/North(+) (400 usft/in)0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 West(-)/East(+) (400 usft/in) WG#1 T90 Tgt1 WG#1 TD Tgt2 16" x 20" 10 3/4 x 13 1/2" 7 5/8" x 9 7/8" 4 1/2" x 6 3/4"1250150017502000225025002750300032503500375040004250450047505000525055005750625067507250775082508750W G #1 w p02aStart Dir 3º/100' : 800' MD, 800'TVD End Dir : 1971.62' MD, 1899.5' TVD Start Dir 3º/100' : 6088.84' MD, 5266'TVD End Dir : 6894.61' MD, 6001.85' TVD Total Depth : 10271.81' MD, 9317' TVD CASING DETAILS TVD TVDSS MD Size Name 120.00 -101.00 120.00 16 16" x 20" 1484.43 1263.43 1500.00 10-3/4 10 3/4 x 13 1/2" 7021.00 6800.00 7932.83 7-5/8 7 5/8" x 9 7/8" 9317.00 9096.00 10271.81 4-1/2 4 1/2" x 6 3/4" Project: Seaview Prospect Site: Whiskey Gulch Well: Prelim: Whiskey Gulch 1 Wellbore: WG#1 Plan: WG#1 wp02a WELL DETAILS: Prelim: Whiskey Gulch 1 203.00 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 2128215.90 168401.60 59° 48' 48.098 N 151° 48' 5.172 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Prelim: Whiskey Gulch 1, True North Vertical (TVD) Reference: WG#1 As-staked RKB @ 221.00usft Measured Depth Reference:WG#1 As-staked RKB @ 221.00usft Calculation Method:Minimum Curvature & ! % $ ! 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"!!!$3!""!< "! = "! + 4!>$ ""!!89";;!"!$"!9!"")9)86%)%3)!:)!%9$ 0.001.002.003.004.00Separation Factor550 1100 1650 2200 2750 3300 3850 4400 4950 5500 6050 6600 7150 7700 8250 8800 9350 9900 10450Measured Depth (1100 usft/in)No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS: Prelim: Whiskey Gulch 1 NAD 1927 (NADCON CONUS) Alaska Zone 04203.00+N/-S+E/-W NorthingEastingLatittudeLongitude0.000.002128215.90168401.6059° 48' 48.098 N 151° 48' 5.172 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Prelim: Whiskey Gulch 1, True NorthVertical (TVD) Reference: WG#1 As-staked RKB @ 221.00usftMeasured Depth Reference:WG#1 As-staked RKB @ 221.00usftCalculation Method:Minimum CurvatureCASING DETAILSTVD TVDSS MD Size Name120.00 -101.00 120.00 16 16" x 20"1484.43 1263.43 1500.00 10-3/4 10 3/4 x 13 1/2"7021.00 6800.00 7932.83 7-5/8 7 5/8" x 9 7/8"9317.00 9096.00 10271.81 4-1/2 4 1/2" x 6 3/4"SURVEY PROGRAMDate: 2020-11-05T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool18.00 1500.00 WG#1 wp02a (WG#1) 3_MWD+AX+Sag1500.00 7932.00 WG#1 wp02a (WG#1) 3_MWD+AX+Sag7932.00 10271.81 WG#1 wp02a (WG#1) 3_MWD+AX+Sag0.0040.0080.00120.00160.00200.00Centre to Centre Separation (80.00 usft/in)550 1100 1650 2200 2750 3300 3850 4400 4950 5500 6050 6600 7150 7700 8250 8800 9350 9900 10450Measured Depth (1100 usft/in)WG#14 wp01WG#15 wp01GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference18.00 To 10271.81Project: Seaview ProspectSite: Whiskey GulchWell: Prelim: Whiskey Gulch 1Wellbore: WG#1Plan: WG#1 wp02aLadder/S.F. Plots Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. X Whiskey Gulch Area X N/A Hilcorp Alaska, LLC Mudlog and cuttings samples are required per 20 AAC 25.071(a). DLB X Whiskey Gulch 1 221-046 WG#1_SHLWhiskeyGulch PadSEC. 234S15WSCHLOESSERCRAIGKERINLEO JOHNKERINBARBARA LEESource: Esri, Maxar, GeoEye, Earthstar Geographics, CNES/Airbus DS, USDA, USGS, AeroGRID,IGN, and the GIS User Community151°48'0"W151°48'10"W151°48'20"W151°48'30"W59°49'0"N59°49'0"N59°48'55"N59°48'55"N59°48'50"N59°48'50"N59°48'45"N59°48'45"N59°48'40"N59°48'40"N59°48'35"N59°48'35"NWhiskey Gulch #1SHL - 660 ft Radius0 100 200 300 400FeetLegendProposed WG#1_SHLWG #1 SHL - 660ft Radius BufferProposed Whiskey Gulch PadKPB Parcels1 inch = 200 feetMap Date: 6/10/2021 Document Path: O:\Alaska\GIS\cook_inlet\fields\WhiskeyGulch\mxds\WhiskeyGulch_#1_wp02a_660ft_Radius_v01.mxd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ig 147 and 169 Diverter Stackup 16'’ Hydril V 4.30' Hydril MSP 21-¼ 2M .50' 4.00' 2.67' 1.33' 4.37' Grade Level 3.09' DSA 16 ¾ 3M X 21 ¼ 2M 21 ¼ 2M Spool 21 ¼ 2M Diverter Tee 16'’ 150 outlet 4.08' 16'’ casing cut @ 64'’ below ground level .42' 1 Carlisle, Samantha J (CED) From:Frank Roach <Frank.Roach@hilcorp.com> Sent:Wednesday, June 16, 2021 9:25 AM To:McLellan, Bryan J (CED) Subject:RE: [EXTERNAL] Rig 169 pit capacity Bryan, Surfacepitcapacityon169is~800bbls.Activesystemisnormallybetween400Ͳ470bblsandtheremainingvolumeis heldinreservetoaddasneeded. Whenasourcewaterwellisnotavailableonlocation,wehavea400bbluprightthat’susedformixwatertobuild additionalmud. Regards, FrankVRoach DrillingEngineer 907.854.2321(c) 907.777.8413(o) From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Tuesday,June15,202117:40 To:FrankRoach<Frank.Roach@hilcorp.com> Subject:[EXTERNAL]Rig169pitcapacity Frank, What’sthepitcapacityonrig169andwhatvolumeofmud,relativetowellborecapacity,doyouplantokeepon location? Thanks BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 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. 1 Carlisle, Samantha J (CED) From:Frank Roach <Frank.Roach@hilcorp.com> Sent:Tuesday, June 29, 2021 3:53 PM To:McLellan, Bryan J (CED) Subject:RE: [EXTERNAL] Whiskey Gulch 1 PTD questions Attachments:Whiskey Gulch wp02 KICK_TOL 06-29-21.XLS; Whiskey Gulch 1 Dry-Hole Tree Configuration.pdf Bryan, ReceivedyouremailaboutbuttoninguptheWhiskeyGulchPTD.Pleaseseetheattached,dryͲholetreewellhead configurationandupdatedkicktolerance.Pertheupdateemail,we’llneedtoreach14.8ppgEMWwhileperformingthe LOTinordertoachieveaminimum15bblkicktolerance. Answerstoyourquestionsareinredandbelowtheirrespectivequestion. Withregardtotheadditionalfluidmonitoringforexplorationwells(thepreviousdiscussionsaround20AAC 25.033(f)(4)&(5)),wouldyouandJimReggbeavailabletomorrow(Wednesday)sometimeforaphoneconversation?I’m wantingtomakesureI’munderstandingtheregulationandnotoverthinkingthis. Thanksforthepermit/programquestionsandletmeknowifyouneedanythingadditional. Regards, FrankVRoach DrillingEngineer 907.854.2321(c) 907.777.8413(o) From:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Sent:Thursday,June24,202118:04 To:FrankRoach<Frank.Roach@hilcorp.com> Subject:[EXTERNAL]WhiskeyGulch1PTDquestions Frank, I’vegotafewmorequestionsabouttheprogramforWhiskeyGulch1: 1. CanyoudoublecheckyourTailcementvolumeonthe7Ͳ5/8”casingcementjob.Ithinkthereisasmall discrepancy,butIcouldbewrong. Thetailvolumewascorrect.Thediscrepancywasinthewrittenoutequation.The“(7,933’Ͳ7,385’)”in theequationshouldread“(7,933’Ͳ7,433’)”todenotethe500’taillength.Programhasbeenupdatedto reflectthecorrectdepth. 2. What’sthedensityofthecompletionfluid? Plannedcompletionfluidis6%KCl.Densityof6%KClis8.65ppg 3. What’satempabandonmentcap?Itdoesnotseemtomatchtheproposedwellhead/treediagramattachedto theprogram.Ataminimum,I’dexpectatubingheadadaptorandonetreevalvenippledupforadryhole tree.Idon’tthinkI’dapproveonlyacapwithaneedlevalve. Agreed.“Tempabandonmentcap”isatermthatI’veonlyseensinceworkinghere.SinceI’vebeen workingtherig,wehaveeitherNUthetree(moreoftenthannot)oradryͲholetreeconfigurationifwe havecellarheightchallenges.Programandtemplatehavebeenupdatedtoreflectthis. 4. Sendanupdatedwellhead/treediagramifitisdifferentthantheoneinthePTD. DryͲholetreeconfigurationisattached. 2 5. OnyourMASPcalculationpagefor6Ͳ3/4”holesection,Idon’tthinkthesummaryiscorrect.Isn’tMASPgoingto begovernedbythelesserofthetwocalculations? Correct.Forthe6Ͳ3/4”holesection,MASPisgovernedbyporepressurewiththewellboreevacuatedto gas.Thecalculationpagehasbeenupdatedandreplacedintheprogram. BryanMcLellan SeniorPetroleumEngineer AlaskaOil&GasConservationCommission Bryan.mclellan@alaska.gov +1(907)250Ͳ9193 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. WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:WHISKEY GULCH 1Initial Class/TypeEXP / PENDGeoArea820Unit50150On/Off ShoreOnProgramEXPField & PoolWell bore segAnnular DisposalPTD#:2210460NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberNo Exploration well.4 Well located in a defined poolNA No unit established at this time.5 Well located proper distance from drilling unit boundaryNA No other wells on this structure.6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes CO 790 already issued for spacing exception.11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)InCmpt18 Conductor string providedInCmpt19 Surface casing protects all known USDWsInCmpt20 CMT vol adequate to circulate on conductor & surf csgInCmpt21 CMT vol adequate to tie-in long string to surf csgInCmpt22 CMT will cover all known productive horizonsInCmpt23 Casing designs adequate for C, T, B & permafrostInCmpt24 Adequate tankage or reserve pitInCmpt25 If a re-drill, has a 10-403 for abandonment been approvedInCmpt26 Adequate wellbore separation proposedInCmpt27 If diverter required, does it meet regulationsInCmpt28 Drilling fluid program schematic & equip list adequateInCmpt29 BOPEs, do they meet regulationInCmpt30 BOPE press rating appropriate; test to (put psig in comments)InCmpt31 Choke manifold complies w/API RP-53 (May 84)InCmpt32 Work will occur without operation shutdownInCmpt33 Is presence of H2S gas probableInCmpt34 Mechanical condition of wells within AOR verified (For service well only)Yes H2S is not present in this hole section in the Anchor Point area.35 Permit can be issued w/o hydrogen sulfide measuresYes36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)Yes39 Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate6/21/2021Appr DateApprDLBDate6/21/2021AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 6/30/21