Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
224-092
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: Workover 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): 16269' None Casing Collapse Conductor Surface Intermediate Seal Bore Diverter Main Bore Screen Liner Main Bore Dual String Mode 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 (907) 265-6379 Staff RWO/CTD Engineer KRU 1H-107 3996' 16269' 3996' 986 None N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Brian.Glasheen@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8996' MD and 3669' TVD 8982' MD and 3665' TVD 9008' MD and 3673' TVD N/A Brian Glasheen STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025636, ADL0025637, ADL0025639 224-092 P.O. Box 100360, Anchorage, AK 99510 50-029-23795-00-00 Kuparuk River field West Sak Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY West Sak Oil Pool TVD Burst 8982' MD 120' 1763' 3903' Perforation Depth TVD (ft): 9253' 120' 1793' 3778'9333' 20" 13-3/8" 80' 9-5/8" 271' 3-1/2" 10075' 1754' 10113' None 103' 4-1/2" None 9.63" 3752' 1/2026 16255'6956' 4-1/2" 3996' Packer: Baker Seal Assembly Packer: Baker SLZXP Packer Packer: Baker Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ons of Approval: ection MIT Req'd? Yes No Subsequent Form Required: Suspension Expiration Date: AOGCC USE ONLY Contact Name: Contact Email: Contact Phone: e: (907)265-6379 Staff RWO/CTD Engineer certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. me and ure with Date:Brian.Glasheen@conocophillips.com Brian Glasheen 15.W ell Status after proposed work: OIL WINJ W DSPL Suspended GAS W AG GSTOR SPLUG GINJ Op Shutdown Abandoned proval: Date: esentative: Date for Operations:1/2026 13.W ell Class after proposed work: Exploratory Stratigraphic Development Service nts: Proposal Summary Wellbore schematic ations Program BOP Sketch SSSV Type: Packers and SSSV MD (ft) and TVD (ft):8996'MD and 3669' TVD 8982'MD and 3665'TVD 9008' MD and 3673' TVD N/A Packer: Baker SLZXP Packer Packer: Baker Seal Assembly SSSV: None Tubing MD (ft): 8982' Tubing Grade:Tubing Size:Perforation Depth TVD (ft): None 4-1/2" pth MD (ft): L-80 Dual ode 9253'271'3-1/2"3752' creen 4-1/2"16255'6956'3996' verter 3778'9333'103'9.63" ate 3903'9-5/8"10075'10113' e 1763'1793'13-3/8"1754' 120'or 120'20"80' CollapseBurstTVDMDSizeLengthg D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD): None3996'16269'3996'986 None MPSP (psi):Plugs (MD): PRESENT WELL CONDITION SUMMARY 10.Field:Current Pools: Kuparuk River field West Sak Oil Pool Proposed Pools: West Sak Oil Pool esignation (Lease Number): 36, ADL0025637, ADL0025639 8.W ell Name and Number: KRU 1H-107 g: ation or Conservation Order governs well spacing in this pool? Yes No N/A quire a spacing exception due to property boundaries? 5.Permit to Drill Number: 6.API Number: 224-092 50-029-23795-00-00 4.Current Well Class: Exploratory Development Stratigraphic Service 360, Anchorage, AK 99510 ame: s Alaska, Inc. quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alteer Casing Other: Workover Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 326-032 By Grace Christianson at 7:32 am, Jan 15, 2026 A.Dewhurst 16JAN26 *AOGCC witnessed BOP and Annular test to 2500 psi. *Variance approved to 20 ACC 25.200 (d) to operate the well under the stipulations of CO 390A. CO 390A Rule 1 - casing tests every 8 years CO 390A Rule 2 - no monobore completions CO 390A Rule 3 - BHP gradient < 8.55 ppg X DSR-1/20/26J.Lau 1/20/25 10-404 JLC 1/21/2026 01/21/26 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 14, 2026 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KRU 1H-107 (PTD# 224-092). Well 1H-107 was spudded in August of 2024 and completed in October of 2024 by Doyon 25 as a West Sak B and C Sand dual lateral producer. The well was initially brought online as a gas lift producer, then converted to an ESP producer when the retrievable AccessESP assembly. The well recently experienced an ESP cable failure and will be converted to gas lift until the workover rig can be moved to the well. Approval is requested to proceed with a rig workover on the subject well. We plan to pull the 4-1/2 ESP completion, perform a cleanout run as needed, then install a new 4-1/2 ESP access ESP completion or a packerless conventional ESP. In the event that a packerless conventional ESP is approved and installed, a variance is requested to 20 ACC 25.200 (d) to operate the well under the stipulations of Hilcorps CO 390A for the Milne Point Unit. 1H-107 reservoir pressure is less than an 8.55 ppg and has a passing casing test to 2500psi. Conoco will test the casing every 8 years and manage the reservoir below a 8.55 ppg to operate without a packer. If you have any questions or require any further information, please contact me at 907-545-1144. Brian Glasheen Rig Workover Engineer CPAI Drilling and Wells Note: 6.87 PPGE - J.Lau 1H-107 West Sak Producer Pull and Replace ESP Completion PTD: 224-092 Page 1 of 2 Pre-Rig Work Remaining 1. T-POT and PPPOT. IC-POT and PPPOT. 2. MIT-IA 2500 psi ( Passed 12-30-2025, This will be the date used to determine the next time casing test is due for a conventional ESP completion.) 3. Prepare well for rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 1H-107. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve 4-1/2 Access ESP Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2 tubing string and jewelry from sealbore at 9,004 RKB. Casing Cleanout/Drift Run 6. MU cleanout/drift BHA, PU drillpipe and perform casing cleanout to sealbore as needed, based on tubing condition. Install New 4-1/2 Access ESP or Packerless Conventional ESP Completion 7. MU new 4-1/2 completion with, ESP assembly, downhole gauge, and gas lift mandrels. RIH to depth. 8. Once on depth, calculate space out. Circulate corrosion inhibited fluid if needed . 9. Land tubing hanger, RILDS. ND BOP, NU Tree 10. Install BPV and test. ND BOPE. NU tree and PT packoffs. 11. Pull BPV and freeze protect well. 12. RDMO. Post-Rig Work 1. Install GLV if needed. 1H-107 West Sak Producer Pull and Replace ESP Completion PTD: 224-092 Page 2 of 2 General Well Information: Estimated Start Date: 1/28/2026 Current Operations: Attempting to bring well online with gas lift Well Type: Producer Wellhead Type: StreamFlo DMLX. 13-3/8 5M tubing head top flange. Scope of Work: Perform a ESP swap. Pull the existing 4-1/2 AccessESP completion from seals, perform a cleanout run as needed based on tubing condition, then install a new 4-1/2 ESP completion. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams MIT Results: MIT-IA: Passed ( 12/30/25) MIT-OA: Open Shoe Static BHP: 1,344 psi / 3,764 TVD measured on 10/28/2024 MPSP: 986 psi using 0.1 psi/ft gradient Personnel: Workover Engineer: Brian Glasheen 907-545-1144 Production Engineer: Marina Krysinski 6.87 PPGE - J.Lau 1H-107 Proposed Access ESP RWO Schematic Description Set Depth MD Set Depth TVD OD ID Weight (lbs)Grade Top Conn Conductor 120 120 20 19.12 78.67 H40 Weld Surface 1793 1762.9 13.375 12.42 68 L-80 Hydril 563 Intermediate 10113 3902.8 9.625 8.84 40 L80 Hydril 563 Mainbore Liner 16255 3996.1 4.5 3.96 12.6 13Cr-80 JFEBear L1 Liner 16126 3926.4 4.5 3.96 12.6 13Cr-80 JFEBear Tubing 9000 3670.4 4.5 3.96 12.6 L-80 Hydril 563 Surface Casing: 1,793' RKB Conductor: Perfs Proposed Completion: 4 1/2" 12.6# L-80 HYD563 Tubing to Surface 4-1/2" x 1.5" GLMs @ TBD 4-1/2" Gauge and Mandrel w/ 1/4" TEC 4-1/2" AccessESP Assembly 4-1/2" NEXA Sliding Sleeve 4-1/2" Locator Seal Assembly @ 9,000' RKB Existing Completion: SLZXP LTP @ 8,982' RKB 190-47 SBE @ 9,004' RKB Baker RAM L5 Junction @ 9,221' RKB B Sand Lateral (Mainbore): 4-1/2" 12.6# 13Cr JFE Bear Casing with Baker Excluder Screens @ 16,255' RKBIntermediate Casing: 9-5/8" 40# L- 80 Hyd563 @ 10,113 D Sand Lateral (L1 Liner): 4-1/2" 12.6# 13Cr JFE Bear Casing with Baker Excluder Screens @ 16,126' RKB RAM L5 Junction Intermediate Casing Calculated TOC: 3,981' RKB Surface Casing TOC: Surface 1H-107 Proposed Packerless ESP RWO Schematic Description Set Depth MD Set Depth TVD OD ID Weight (lbs)Grade Top Conn Conductor 120 120 20 19.12 78.67 H40 Weld Surface 1793 1762.9 13.375 12.42 68 L-80 Hydril 563 Intermediate 10113 3902.8 9.625 8.84 40 L80 Hydril 563 Mainbore Liner 16255 3996.1 4.5 3.96 12.6 13Cr-80 JFEBear L1 Liner 16126 3926.4 4.5 3.96 12.6 13Cr-80 JFEBear Tubing 9000 3670.4 4.5 3.96 12.6 L-80 Hydril 563 Surface Casing: 1,793' RKB Conductor: Perfs Proposed Completion: 4 1/2" 12.6# L-80 HYD563 Tubing to Surface 4-1/2" x 1.5" GLMs @ TBD 4-1/2" X nip 4-1/2" Packerless Conventional ESP Assembly Existing Completion: SLZXP LTP @ 8,982' RKB 190-47 SBE @ 9,004' RKB Baker RAM L5 Junction @ 9,221' RKB B Sand Lateral (Mainbore): 4-1/2" 12.6# 13Cr JFE Bear Casing with Baker Excluder Screens @ 16,255' RKBIntermediate Casing: 9-5/8" 40# L- 80 Hyd563 @ 10,113 D Sand Lateral (L1 Liner): 4-1/2" 12.6# 13Cr JFE Bear Casing with Baker Excluder Screens @ 16,126' RKB RAM L5 Junction Intermediate Casing Calculated TOC: 3,981' RKB Surface Casing TOC: Surface 1H-107 | 1H-107L1Dual Lateral Producer1H-107 | 1H-107L1Dual Lateral ProducerAs DrilledRKB = 93 AMSLAs DrilledRKB = 93 AMSL20'' 94# H40 Welded Insulated Conductor120'/120' TVDCemented to Surface20'' 94# H40 Welded Insulated Conductor120'/120' TVDCemented to SurfaceProduction Tubing4-1/2'' 12.6# L80 H563Production Tubing4-1/2'' 12.6# L80 H563Intermediate Casing9-5/8'' 40# L80 H56310113'/3893' TVDIntermediate Casing9-5/8'' 40# L80 H56310113'/3893' TVDSLZXP LTP8982'/3664' TVDSLZXP LTP8982'/3664' TVDWindow Top Bottom 9237'-9254' MDWindow Top Bottom 9237'-9254' MDBaker RAM L5 Junction, 13Cr-80 Dual Seal Module, 9221'/ 3741' TVD RAM Hanger, 9225'/ 3742' TVDSealbore Diverter, 9230'/ 3744' TVD Baker RAM L5 Junction, 13Cr-80 Dual Seal Module, 9221'/ 3741' TVD RAM Hanger, 9225'/ 3742' TVDSealbore Diverter, 9230'/ 3744' TVD MLZXP LTP9299'/3767' TVDMLZXP LTP9299'/3767' TVDIntermediate TOC (25% washout)3479'/2860' TVDIntermediate TOC (25% washout)3479'/2860' TVDMain Bore: 1H-1074-1/2'' 12.6# 13CR-80 JFE BEAR16255'/3996' TVD6-3/4'' Production Hole16269'/3996' TVDMain Bore: 1H-1074-1/2'' 12.6# 13CR-80 JFE BEAR16255'/3996' TVD6-3/4'' Production Hole16269'/3996' TVDUpper Lateral: 1H-107L14-1/2'' 12.6# 13CR-80 JFE BEAR16126'/3926' TVD6-3/4'' Production Hole16163'/3925' TVDUpper Lateral: 1H-107L14-1/2'' 12.6# 13CR-80 JFE BEAR16126'/3926' TVD6-3/4'' Production Hole16163'/3925' TVDUGNU C 5035'/3081' TVDUGNU C 5035'/3081' TVDWEST SAK B 10042'/3899' TVDWEST SAK B 10042'/3899' TVDWEST SAK D 9598'/3846' TVDWEST SAK D 9598'/3846' TVDSurface Casing13-3/8'' 68# L80 H5631793'/1763' TVDCemented to SurfaceSurface Casing13-3/8'' 68# L80 H5631793'/1763' TVDCemented to SurfaceBaker Excluder 107 um Open Hole Standalone Screens | TAM 6.38" OD Water Swell Packer | Davis Lynch Shoe Baker Excluder 107 um Open Hole Standalone Screens | TAM 6.38" OD Water Swell Packer | Davis Lynch Shoe Baker Excluder 107 um Open Hole Standalone Screens | TAM 6.38" OD Water Swell Packer | Davis Lynch Shoe Baker Excluder 107 um Open Hole Standalone Screens | TAM 6.38" OD Water Swell Packer | Davis Lynch Shoe Upper Completion1. SLB 1.0" KBMG Gas Lift Mandrel (x2)2. HAL Single Gauge Mandrel3. Baker AccessESP Assembly4. SLB CMU Sliding Sleeve (3.813" X profile)5. HAL Chemical Injection Mandrel, with 13Cr-80 JFE Bearbottom pup joint6. 13Cr-80 Baker Locator, HAL Mule Shoe, and SealAssemblyUpper Completion1. SLB 1.0" KBMG Gas Lift Mandrel (x2)2. HAL Single Gauge Mandrel3. Baker AccessESP Assembly4. SLB CMU Sliding Sleeve (3.813" X profile)5. HAL Chemical Injection Mandrel, with 13Cr-80 JFE Bearbottom pup joint6. 13Cr-80 Baker Locator, HAL Mule Shoe, and SealAssembly Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull ACP ISO, Shift Sleeves open, Set ESP 1H-107 3/26/2025 appleha Notes: General & Safety Annotation End Date Last Mod By Note: Chrome tubing below 8,939'famaj Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread Conductor 20 19.12 39.7 120.0 120.0 78.67 B Surface 13 3/8 12.42 39.5 1,793.0 1,762.9 68.00 L-80 H563 Seal Bore Diverter 9.63 7.76 9,230.1 9,333.4 3,777.6 29.70 13Cr-80 N/A Intermediate 9 5/8 8.84 38.2 10,112.7 3,902.8 40.00 L-80 Hydril 563 Main bore Screen liner 4 1/2 3.96 9,298.7 16,254.5 3,996.1 12.60 13CR-80 JFEBear Main Bore Dual string module 3 1/2 2.99 8,982.1 9,253.3 3,752.2 9.20 13Cr-80 VamTop Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth 9,000.3 Set Depth 3,670.4 String Max No 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.9 36.9 0.00 Hanger 13.475 Streamflo hanger 4" H BPV, 6.25" acme lift threads - S/N StreamF lo DMLX 3.900 2,840.0 2,582.9 54.09 Mandrel 4.500 4-1/2" x 1" KBMG-1 GLM S/N 24190-09 SLB 4.5" x 1" KBMG 3.865 6,923.1 3,339.2 82.15 Mandrel 4.500 4-1/2" x 1" KBMG-1 GLM S/N 24190-05 SLB 4.5" x 1" KBMG 3.865 8,361.3 3,532.4 82.40 Gauge / Pump Sensor 6.077 HES Opsis Gauge mandrel w/ Downhole gauge, 4-1/2" H563, L80 HES 3.919 8,465.5 3,546.2 82.42 Sliding Sleeve 5.500 5-1/2" GV CMD Sliding sleeve 4 1/2" Vamtop Box x 5 1/2", 23#, Vam FJL Box ************ OPENED 3/23/25*************** Access ESP Sliding Sleeve 3.910 8,471.8 3,547.1 82.43 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,476.6 3,547.7 82.43 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,478.3 3,547.9 82.43 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,483.1 3,548.5 82.43 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,484.9 3,548.8 82.44 Motor Shroud 5.500 Motor Shroud, 5 1/2" Vam FJL Box x Pin Access ESP 3.894 8,489.7 3,549.4 82.44 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 4.548 8,491.4 3,549.6 82.44 Motor Shroud 5.500 Motor Shroud, 5 1/2" Vam FJL Box x Pin Access ESP 4.548 8,496.3 3,550.3 82.44 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,498.0 3,550.5 82.44 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,502.9 3,551.1 82.45 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,504.6 3,551.4 82.45 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,509.4 3,552.0 82.45 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,511.2 3,552.2 82.45 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,515.9 3,552.9 82.46 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,517.7 3,553.1 82.46 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,522.5 3,553.7 82.46 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,524.3 3,554.0 82.43 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,530.6 3,554.8 82.25 Annular Connection Port 5.950 Ann Connection Port, 5", 18# Vam FJL Box x 4 1/2" 12.6# Vamtop Box Access ESP 3.860 8,554.2 3,558.1 81.60 Profile Sub 4.500 B-Profile, 4 1/2", 12.6#, L-80 Vamtop Box x Box Access ESP 3.913 8,567.7 3,560.1 81.22 No-go nipple 5.000 No-Go, 4 1/2" 12.6# Vamtop Box x 4 1/2" Hyd 563 Box 3.805 8,873.3 3,630.1 72.37 Sliding Sleeve 5.490 CMU Sliding sleeve, 3.813" X Profile, 4-1/2", 12.6#, L80, H563 ******OPENED 3/22/25************ Camco NEXA CMU 3.813 8,939.1 3,650.7 71.39 Mandrel 5.600 HES Chemical injection mandrel, 4- 1/2" 12.6#, L80, H563 HES 4.330 8,999.5 3,670.1 71.11 Locator 5.190 Baker Locater 13Cr-80 3.880 9,000.3 3,670.4 71.10 Spacer tubes 13Cr-80 (10.68) 5.190 9,000.3 3,670.4 71.10 Baker Seal assembly 5.190 Baker 192-47 Seal assemblyw/ 3' of seals (3.18) 9,000.3 3,670.4 71.10 Mule Shoe Guide 5.190 Halliburton Self Aligning mule shoe guide (3.99) MULTIPLE LATERALS, 1H-107, 3/31/2025 12:44:56 PM Vertical schematic (actual) Main bore Screen liner; 9,298.7- 16,254.5 Float Shoe; 16,251.8-16,254.5 Casing Jts; 16,212.2-16,251.8 Drillable Pack Off Sub; 16,201.4- 16,202.6 Casing - Production Pup; 16,191.8-16,201.4 Casing-Screen; 15,476.3- 16,191.8 Packer - Swell 1; 15,456.6- 15,476.3 Casing-Screen; 14,741.0- 15,456.6 Packer - Swell 2; 14,721.3- 14,741.0 Packer - Swell 3; 14,224.4- 14,244.2 Casing-Screen; 13,072.0- 14,224.4 Packer - Swell 4; 13,052.3- 13,072.0 Casing-Screen; 10,470.6- 13,052.3 Packer - Swell 5; 10,450.9- 10,470.6 Packer - Swell 6; 10,311.3- 10,331.1 Casing-Screen; 10,113.1- 10,311.3 Intermediate; 38.2-10,112.7 Float Shoe; 10,109.6-10,112.7 Float Collar; 10,021.5-10,024.2 Casing - Production Pup; 9,393.5-9,396.6 XO Reducing; 9,392.0-9,393.5 Casing Jts; 9,352.3-9,392.0 XO Reducing; 9,348.5-9,352.3 C-2 Knock Out Isolation Valve; 9,346.2-9,348.5 KOIV Isolation Tool; 9,343.1- 9,346.2 XO Enlarging; 9,336.4-9,343.1 Seal Bore Diverter; 9,230.1- 9,333.4 Shoe - Mule; 9,330.1-9,333.4 XO Reducing; 9,325.2-9,326.7 Anchor; 9,311.7-9,314.0 Liner Hanger; 9,298.7-9,325.2 Anchor; 9,307.1-9,311.7 Nipple; 9,286.1-9,287.4 Main Bore Dual string module; 8,982.1-9,253.3 Seal Assembly; 9,233.9-9,253.3 L1 Screen Liner; 9,225.5- 16,125.6 L1 Dual String module; 8,982.1- 9,267.1 Seal Assembly; 9,233.9-9,267.1 Hanger; 9,233.1-9,262.3 Dual Seal Module; 9,228.0- 9,233.9 Dual Seal Module; 9,228.0- 9,233.9 Hanger; 9,225.5-9,233.1 Dual Seal Module; 9,201.5- 9,228.0 Dual Seal Module; 9,201.5- 9,228.0 Nipple - XN; 9,189.0-9,190.3 Nipple - XN; 9,138.6-9,139.9 Swivel; 9,126.3-9,128.8 Swivel; 9,122.0-9,124.6 Selective Re-entry Tool; 9,088.5- 9,108.5 Selective Re-entry Tool; 9,088.4- 9,108.5 Swivel; 9,074.3-9,078.0 Swivel; 9,074.3-9,078.0 XO Threads; 9,053.0-9,054.6 XO Threads; 9,052.9-9,054.6 FLCV; 9,035.6-9,042.4 FLCV; 9,035.5-9,042.4 SBR; 9,005.1-9,024.8 SBR; 9,005.0-9,024.8 PACKER ; 8,982.1-9,003.7 PACKER - LINER; 8,982.1- 9,003.6 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 No-go nipple; 8,567.7 Profile Sub; 8,554.2 Annular Connection Port; 8,530.6 Motor Shroud; 8,524.3 Motor Centralizer; 8,522.5 Motor Shroud; 8,517.7 Motor Centralizer; 8,515.9 Motor Shroud; 8,511.2 ESP MOTOR; 8,482.0 Motor Centralizer; 8,509.4 Motor Shroud; 8,504.6 Motor Centralizer; 8,502.8 Motor Shroud; 8,498.0 Motor Centralizer; 8,496.3 Motor Shroud; 8,491.4 Motor Centralizer; 8,489.7 Motor Shroud; 8,484.9 Motor Centralizer; 8,483.1 Motor Shroud; 8,478.3 Motor Centralizer; 8,476.6 Motor Shroud; 8,471.8 Sliding Sleeve; 8,465.5 ESP; 8,435.0 RBP; 8,428.9 Gauge / Pump Sensor; 8,361.3 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 6,923.1 Annular Fluid - Saltwater/Brine; 2,839.0-9,233.0; 10/5/2024 Mandrel; 2,840.0 Surface; 39.5-1,793.0 Float Shoe; 1,789.4-1,793.0 Annular Fluid - Diesel; 36.0- 2,839.0; 10/5/2024 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Casing Jts; 39.7-120.0 Casing Hanger; 39.5-40.2 Casing Hanger; 38.2-38.8 Hanger; 36.9 KUP PROD KB-Grd (ft) 39.50 RR Date 10/5/2024 Other Elev 1H-107 ... TD Act Btm (ftKB) 16,269.0 Well Attributes Field Name Wellbore API/UWI 500292379500 Wellbore Status PROD Max Angle & MD Incl (°) 92.92 MD (ftKB) 15,635.59 WELLNAME WELLBORE1H-107 Annotation End DateH2S (ppm)DateComment Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,428.9 3,541.4 82.40 RBP 4.5" P2P PACKER, HANGOFF XO, STANDING VALVE WITH CHECK BALL AND SEAL STINGER, STUNG INTO TOP OF PUMP. CPP4 5036 3/26/2025 2.000 8,435.0 3,542.2 82.40 ESP 53.20' SUMMIT DUAL STAGE PUMP, 380, 67 STG, SF5800, T52. 3/25/2025 8,482.0 3,548.4 82.43 ESP MOTOR 57' ACCESS ESP 250 HP 4 POLE PPM MOTOR. 3/25/2025 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,840.0 2,582.9 54.09 1 GAS LIFT DMY BK 1 3/21/2025 SLB KBMG 6,923.1 3,339.2 82.15 2 GAS LIFT SOV BK 1 3/21/2025 2400#SLB KBMG Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,982.1 3,664.5 71.18 PACKER 9.625 Baker SLZXP w/ HD 10' ext, 9- 5/8" x 7" 29# H563 pin down 13 Cr -80 TOL xxxx' Baker SLZXP 7.380 9,003.7 3,671.5 71.10 XO Threads 7.000 Crossover sub, 7" 26# H563 x 5- 1/2" 15.5# H563 pin 13Cr-80 4.890 9,005.1 3,672.0 71.10 SBR 5.500 Baker 190-47 Seal bore, 5-1/2" 15.5# H563 B x P, 13Cr-80 Baker SBE 4.750 9,033.9 3,681.3 71.07 XO Threads 7.000 Crossover sub, 5-1/2" H563 x 7" H563, 13Cr-80 4.950 9,035.6 3,681.8 71.07 FLCV 7.000 7" FLCV, 7" H563 BxP 13Cr-80 (Locked open by pressuring up, sheared @ 2250 PSI, on 10/13/24) Baker 4.570 9,042.4 3,684.1 71.06 XO Threads 7.000 Crossover sub, 7" H563 x 5-1/2" H563, 13Cr-80 4.950 9,053.0 3,687.5 71.05 XO Threads 5.500 Crossover sub, 5-1/2" H563 x 4- 1/2" H563, 13Cr-80 Baker 3.850 9,054.6 3,688.0 71.05 XO Threads 4.500 Crossover sub, 4-1/2" H563 x 4- 1/2" VamTop, 13Cr-80 3.850 9,074.3 3,694.4 71.03 Swivel 4.500 Telescoping swivel sub, 4-1/2" VamTop, 13Cr-80, 24" Stroke Baker 3.870 9,088.5 3,699.0 71.02 Selective Re- entry Tool 4.500 Selective re-entry tool (MB and L1), 4-1/2" VT Box x (2) 3-1/2" VT box down Baker SRT 3.740 9,122.0 3,709.9 71.09 Swivel 3.500 Swivel Sub (mainbore) 3-1/2" 9.2#, VamTop BxP, 13Cr-80 Baker 2.960 9,138.7 3,715.3 71.13 Nipple - XN 3.500 2.813" XN, WITH A 2.75" NO-GO (mainbore), 3-1/2" 9.2# VamTop 13Cr-80 HES XN 2.750 9,183.0 3,729.6 71.22 XO Threads 3.500 Main bore XO 3-1/2" VT x 3.220" 7.9# SSDS-8 Pin 2.700 9,230.1 3,744.8 71.27 Window 9.630 Baker Seal Bore diverter, L5. Pos #1, 4-1/2" H563 pin (6.75' above TOW) 13Cr Baker RAM L5 SBD L1 7.760 9,257.8 3,753.6 71.30 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" H563 x JFE Bear 13Cr-80 3.900 9,286.1 3,762.7 71.38 Nipple 4.500 No Go sub w/ 2.6" Tapered ID, 4- 1/2" JFE Bear 13Cr-80 Baker No Go 2.600 9,287.4 3,763.1 71.39 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" JFE Bear x H563, 13Cr-80 3.910 9,307.1 3,769.4 71.54 Anchor 7.300 RAM ML Production Anchor (120k snap) 4-1/2" 12.6# 13Cr-80 above collet Baker RAM XL 3.910 9,311.7 3,770.8 71.57 Anchor 6.250 RAM ML Production Anchor (120k snap) 4-1/2" 12.6# 13Cr-80 below collet Baker RAM XL 3.910 9,314.0 3,771.6 71.59 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" H563 x STL pin, 4-1/2" 12.6#, 13Cr-80 3.890 9,325.2 3,775.1 71.67 XO Reducing 7.650 Baker 4.900 9,336.4 3,778.6 71.75 XO Enlarging 5.500 Baker 4.890 9,343.1 3,780.7 71.80 KOIV Isolation Tool 8.030 Baker KOIV 5.150 9,346.2 3,781.7 71.82 C-2 Knock Out Isolation Valve 7.000 C-2 Knock Out Isolation Valve Baker 6.120 9,348.6 3,782.4 71.84 XO Reducing 5.500 Baker 4.900 9,392.0 3,795.7 72.62 XO Reducing 4.500 3.958 10,311.4 3,906.4 90.85 Packer - Swell 6 4.500 TAM 3.958 10,450.9 3,904.1 91.10 Packer - Swell 5 4.500 TAM 3.958 13,052.3 3,941.2 87.25 Packer - Swell 4 4.500 TAM 3.958 14,224.4 3,986.8 88.39 Packer - Swell 3 4.500 TAM 3.958 14,721.3 4,012.0 87.34 Packer - Swell 2 4.500 TAM 3.958 15,456.6 4,014.1 91.18 Packer - Swell 1 4.500 TAM 3.958 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 39.7 1,793.0 39.7 1,762.9 Surface String Cement Pump 100 BBLS 10.9 PPG mud push, Pump 308 BBLS 11 PPG lead cement, see mud push at surface 280 BBLS away into lead, pump 71 BBLS 15.8 PPG tail cement, pump 20 BBLS H2O, chase with 232 BBLS 9.6 PPG spud mud, see 11.0 PPG lead cement at surface at 180 BBLS into Displacement, bump plugs, check floats, floats hold. 8/20/2024 MULTIPLE LATERALS, 1H-107, 3/31/2025 12:44:59 PM Vertical schematic (actual) Main bore Screen liner; 9,298.7- 16,254.5 Float Shoe; 16,251.8-16,254.5 Casing Jts; 16,212.2-16,251.8 Drillable Pack Off Sub; 16,201.4- 16,202.6 Casing - Production Pup; 16,191.8-16,201.4 Casing-Screen; 15,476.3- 16,191.8 Packer - Swell 1; 15,456.6- 15,476.3 Casing-Screen; 14,741.0- 15,456.6 Packer - Swell 2; 14,721.3- 14,741.0 Packer - Swell 3; 14,224.4- 14,244.2 Casing-Screen; 13,072.0- 14,224.4 Packer - Swell 4; 13,052.3- 13,072.0 Casing-Screen; 10,470.6- 13,052.3 Packer - Swell 5; 10,450.9- 10,470.6 Packer - Swell 6; 10,311.3- 10,331.1 Casing-Screen; 10,113.1- 10,311.3 Intermediate; 38.2-10,112.7 Float Shoe; 10,109.6-10,112.7 Float Collar; 10,021.5-10,024.2 Casing - Production Pup; 9,393.5-9,396.6 XO Reducing; 9,392.0-9,393.5 Casing Jts; 9,352.3-9,392.0 XO Reducing; 9,348.5-9,352.3 C-2 Knock Out Isolation Valve; 9,346.2-9,348.5 KOIV Isolation Tool; 9,343.1- 9,346.2 XO Enlarging; 9,336.4-9,343.1 Seal Bore Diverter; 9,230.1- 9,333.4 Shoe - Mule; 9,330.1-9,333.4 XO Reducing; 9,325.2-9,326.7 Anchor; 9,311.7-9,314.0 Liner Hanger; 9,298.7-9,325.2 Anchor; 9,307.1-9,311.7 Nipple; 9,286.1-9,287.4 Main Bore Dual string module; 8,982.1-9,253.3 Seal Assembly; 9,233.9-9,253.3 L1 Screen Liner; 9,225.5- 16,125.6 L1 Dual String module; 8,982.1- 9,267.1 Seal Assembly; 9,233.9-9,267.1 Hanger; 9,233.1-9,262.3 Dual Seal Module; 9,228.0- 9,233.9 Dual Seal Module; 9,228.0- 9,233.9 Hanger; 9,225.5-9,233.1 Dual Seal Module; 9,201.5- 9,228.0 Dual Seal Module; 9,201.5- 9,228.0 Nipple - XN; 9,189.0-9,190.3 Nipple - XN; 9,138.6-9,139.9 Swivel; 9,126.3-9,128.8 Swivel; 9,122.0-9,124.6 Selective Re-entry Tool; 9,088.5- 9,108.5 Selective Re-entry Tool; 9,088.4- 9,108.5 Swivel; 9,074.3-9,078.0 Swivel; 9,074.3-9,078.0 XO Threads; 9,053.0-9,054.6 XO Threads; 9,052.9-9,054.6 FLCV; 9,035.6-9,042.4 FLCV; 9,035.5-9,042.4 SBR; 9,005.1-9,024.8 SBR; 9,005.0-9,024.8 PACKER ; 8,982.1-9,003.7 PACKER - LINER; 8,982.1- 9,003.6 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 No-go nipple; 8,567.7 Profile Sub; 8,554.2 Annular Connection Port; 8,530.6 Motor Shroud; 8,524.3 Motor Centralizer; 8,522.5 Motor Shroud; 8,517.7 Motor Centralizer; 8,515.9 Motor Shroud; 8,511.2 ESP MOTOR; 8,482.0 Motor Centralizer; 8,509.4 Motor Shroud; 8,504.6 Motor Centralizer; 8,502.8 Motor Shroud; 8,498.0 Motor Centralizer; 8,496.3 Motor Shroud; 8,491.4 Motor Centralizer; 8,489.7 Motor Shroud; 8,484.9 Motor Centralizer; 8,483.1 Motor Shroud; 8,478.3 Motor Centralizer; 8,476.6 Motor Shroud; 8,471.8 Sliding Sleeve; 8,465.5 ESP; 8,435.0 RBP; 8,428.9 Gauge / Pump Sensor; 8,361.3 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 6,923.1 Annular Fluid - Saltwater/Brine; 2,839.0-9,233.0; 10/5/2024 Mandrel; 2,840.0 Surface; 39.5-1,793.0 Float Shoe; 1,789.4-1,793.0 Annular Fluid - Diesel; 36.0- 2,839.0; 10/5/2024 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Casing Jts; 39.7-120.0 Casing Hanger; 39.5-40.2 Casing Hanger; 38.2-38.8 Hanger; 36.9 KUP PROD 1H-107 ... WELLNAME WELLBORE1H-107 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 3,981.0 10,112.0 2,942.8 3,902.8 Intermediate String 1 Cement 8/29/2024 MULTIPLE LATERALS, 1H-107, 3/31/2025 12:45:01 PM Vertical schematic (actual) Main bore Screen liner; 9,298.7- 16,254.5 Float Shoe; 16,251.8-16,254.5 Casing Jts; 16,212.2-16,251.8 Drillable Pack Off Sub; 16,201.4- 16,202.6 Casing - Production Pup; 16,191.8-16,201.4 Casing-Screen; 15,476.3- 16,191.8 Packer - Swell 1; 15,456.6- 15,476.3 Casing-Screen; 14,741.0- 15,456.6 Packer - Swell 2; 14,721.3- 14,741.0 Packer - Swell 3; 14,224.4- 14,244.2 Casing-Screen; 13,072.0- 14,224.4 Packer - Swell 4; 13,052.3- 13,072.0 Casing-Screen; 10,470.6- 13,052.3 Packer - Swell 5; 10,450.9- 10,470.6 Packer - Swell 6; 10,311.3- 10,331.1 Casing-Screen; 10,113.1- 10,311.3 Intermediate; 38.2-10,112.7 Float Shoe; 10,109.6-10,112.7 Float Collar; 10,021.5-10,024.2 Casing - Production Pup; 9,393.5-9,396.6 XO Reducing; 9,392.0-9,393.5 Casing Jts; 9,352.3-9,392.0 XO Reducing; 9,348.5-9,352.3 C-2 Knock Out Isolation Valve; 9,346.2-9,348.5 KOIV Isolation Tool; 9,343.1- 9,346.2 XO Enlarging; 9,336.4-9,343.1 Seal Bore Diverter; 9,230.1- 9,333.4 Shoe - Mule; 9,330.1-9,333.4 XO Reducing; 9,325.2-9,326.7 Anchor; 9,311.7-9,314.0 Liner Hanger; 9,298.7-9,325.2 Anchor; 9,307.1-9,311.7 Nipple; 9,286.1-9,287.4 Main Bore Dual string module; 8,982.1-9,253.3 Seal Assembly; 9,233.9-9,253.3 L1 Screen Liner; 9,225.5- 16,125.6 L1 Dual String module; 8,982.1- 9,267.1 Seal Assembly; 9,233.9-9,267.1 Hanger; 9,233.1-9,262.3 Dual Seal Module; 9,228.0- 9,233.9 Dual Seal Module; 9,228.0- 9,233.9 Hanger; 9,225.5-9,233.1 Dual Seal Module; 9,201.5- 9,228.0 Dual Seal Module; 9,201.5- 9,228.0 Nipple - XN; 9,189.0-9,190.3 Nipple - XN; 9,138.6-9,139.9 Swivel; 9,126.3-9,128.8 Swivel; 9,122.0-9,124.6 Selective Re-entry Tool; 9,088.5- 9,108.5 Selective Re-entry Tool; 9,088.4- 9,108.5 Swivel; 9,074.3-9,078.0 Swivel; 9,074.3-9,078.0 XO Threads; 9,053.0-9,054.6 XO Threads; 9,052.9-9,054.6 FLCV; 9,035.6-9,042.4 FLCV; 9,035.5-9,042.4 SBR; 9,005.1-9,024.8 SBR; 9,005.0-9,024.8 PACKER ; 8,982.1-9,003.7 PACKER - LINER; 8,982.1- 9,003.6 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 No-go nipple; 8,567.7 Profile Sub; 8,554.2 Annular Connection Port; 8,530.6 Motor Shroud; 8,524.3 Motor Centralizer; 8,522.5 Motor Shroud; 8,517.7 Motor Centralizer; 8,515.9 Motor Shroud; 8,511.2 ESP MOTOR; 8,482.0 Motor Centralizer; 8,509.4 Motor Shroud; 8,504.6 Motor Centralizer; 8,502.8 Motor Shroud; 8,498.0 Motor Centralizer; 8,496.3 Motor Shroud; 8,491.4 Motor Centralizer; 8,489.7 Motor Shroud; 8,484.9 Motor Centralizer; 8,483.1 Motor Shroud; 8,478.3 Motor Centralizer; 8,476.6 Motor Shroud; 8,471.8 Sliding Sleeve; 8,465.5 ESP; 8,435.0 RBP; 8,428.9 Gauge / Pump Sensor; 8,361.3 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 6,923.1 Annular Fluid - Saltwater/Brine; 2,839.0-9,233.0; 10/5/2024 Mandrel; 2,840.0 Surface; 39.5-1,793.0 Float Shoe; 1,789.4-1,793.0 Annular Fluid - Diesel; 36.0- 2,839.0; 10/5/2024 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Casing Jts; 39.7-120.0 Casing Hanger; 39.5-40.2 Casing Hanger; 38.2-38.8 Hanger; 36.9 KUP PROD 1H-107 ... WELLNAME WELLBORE1H-107 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: Workover 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): 16269' None Casing Collapse Conductor Surface Intermediate Seal Bore Diverter Main Bore Screen Liner Main Bore Dual String Mode 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 3752' 1/14/2026 16255'6956' 4-1/2" 3996' Packer: Baker Seal Assembly Packer: Baker SLZXP Packer Packer: Baker Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 271' 3-1/2" 10075' 1754' 10113' None 103' 4-1/2" None 9.63" Perforation Depth TVD (ft): 9253' 120' 1793' 3778'9333' 20" 13-3/8" 80' 9-5/8" 8982' MD 120' 1763' 3903' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY West Sak Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025636, ADL0025637, ADL0025639 224-092 P.O. Box 100360, Anchorage, AK 99510 50-029-23795-00-00 Kuparuk River field West Sak Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8996' MD and 3669' TVD 8982' MD and 3665' TVD 9008' MD and 3673' TVD N/A Brian Glasheen Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Brian.Glasheen@conocophillips.com (907) 265-6379 Staff RWO/CTD Engineer KRU 1H-107 3996' 16269' 3996' 986 None N/A approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ons of Approval: ection MIT Req'd? Yes No Subsequent Form Required: Suspension Expiration Date: AOGCC USE ONLY Contact Name: Contact Email: Contact Phone: e: Brian Glasheen certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. me and ure with Date:Brian.Glasheen@conocophillips.com (907)265-6379 Staff RWO/CTD Engineer 15. Well Status after proposed work: OIL WINJ W DSPL Suspended GAS WAG GSTOR SPLUG GINJ Op Shutdown Abandoned proval: Date: esentative: Date for Operations:1/14/2026 13. Well Class after proposed work: Exploratory Stratigraphic Development Service nts: Proposal Summary Wellbore schematic ations Program BOP Sketch SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Packer: Baker SLZXP Packer Packer: Baker Seal Assembly SSSV: None 8996'MD and 3669' TVD 8982'MD and 3665'TVD 9008' MD and 3673' TVD N/A 8982' Tubing MD (ft): L-80 Tubing Grade: 4-1/2" Tubing Size: None Perforation Depth TVD (ft):pth MD (ft): 3752'9253'3-1/2"Dual ode 271' 3996'16255'4-1/2"6956'creen 3778'9333'9.63"103'verter 3903'10113'9-5/8"10075'ate 1763'1793'13-3/8"1754'e 120'120'20"80'or CollapseBurstTVDMDSizeLengthg D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD): None MPSP (psi): Plugs (MD): 3996'16269'3996'986 None PRESENT WELL CONDITION SUMMARY 10. Field:Proposed Pools: West Sak Oil Pool Kuparuk River field West Sak Oil Pool Current Pools:esignation (Lease Number): 36, ADL0025637, ADL0025639 8. Well Name and Number:g: ation or Conservation Order governs well spacing in this pool? Yes Noquire a spacing exception due to property boundaries? KRU 1H-107N/A 5. Permit to Drill Number: 6. API Number: 224-092 50-029-23795-00-00 4.Current Well Class: Exploratory Development Stratigraphic Service 360, Anchorage, AK 99510 ame: s Alaska, Inc. quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alteer Casing Other: Workover Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 326-001 By Grace Christianson at 7:58 am, Jan 02, 2026 DSR-1/2/26A.Dewhurst 02JAN25 X J.Lau 1/6/25 AOGCC witnessed BOP and Annular test to 2500 psi. 10-404 01/06/26 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 31, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KRU 1H-107 (PTD# 224-092). Well 1H-107 was spudded in August of 2024 and completed in October of 2024 by Doyon 25 as a West Sak B and C Sand dual lateral producer. The well was initially brought online as a gas lift producer, then converted to an ESP producer when the retrievable AccessESP assembly. The well recently experienced an ESP cable failure and will be converted to gas lift until the workover rig can be moved to the well. We are requesting approval to proceed with a rig workover. We plan to pull the 4-1/2 ESP completion, perform a cleanout run as needed, then install a new 4-1/2 ESP completion. If you have any questions or require any further information, please contact me at 907-545-1144. Brian Glasheen Rig Workover Engineer CPAI Drilling and Wells 1H-107 West Sak Producer Pull and Replace ESP Completion PTD: 224-092 Page 1 of 2 Pre-Rig Work Remaining 1. T-POT and PPPOT. IC-POT and PPPOT. 2. Set RBP at 9068 CMIT-1500 psi 3. Pull isolation sleeve or pull valve from GLM for circulation point. 4. Prepare well for rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 1H-107. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve 4-1/2 Access ESP Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2 tubing string and jewelry from sealbore at 9,004 RKB. Casing Cleanout/Drift Run 6. MU cleanout/drift BHA, PU drillpipe and perform casing cleanout to sealbore as needed, based on tubing condition. Install New 4-1/2 Access ESP Completion 7. MU new 4-1/2 completion with seal assembly, AccessESP assembly, downhole gauge, and gas lift mandrels. RIH to sealbore. 8. Once on depth, sting into sealbore, calculate space out. Circulate corrosion inhibited fluid. 9. Land tubing in sealbore, land tubing hanger, RILDS. 10. Pressure test tubing to 3,000 psi for 30 minutes. 11. Pressure test IA to 2,500 psi for 30 minutes. ND BOP, NU Tree 12. Confirm pressure tests, then shear out SOV. 13. Install BPV and test. ND BOPE. NU tree and PT packoffs. 14. Pull BPV and freeze protect well. 15. RDMO. Post-Rig Work 1. Pull SOV. Install new DMY. 2. Install retrievable AccessESP assembly. 3. 1H-107 West Sak Producer Pull and Replace ESP Completion PTD: 224-092 Page 2 of 2 General Well Information: Estimated Start Date: 1/14/2026 Current Operations: Attempting to bring well online with gas lift Well Type: Producer Wellhead Type: StreamFlo DMLX. 13-3/8 5M tubing head top flange. Scope of Work: Perform a like-kind pull and replace of the 4-1/2 AccessESP. Pull the existing 4- 1/2 AccessESP completion from seals, perform a cleanout run as needed based on tubing condition, then install a new 4-1/2 AccessESP completion. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams MIT Results: MIT-IA: Passed ( 12/30/25) MIT-OA: Open Shoe Static BHP: 1,344 psi / 3,764 TVD measured on 10/28/2024 MPSP: 986 psi using 0.1 psi/ft gradient Personnel: Workover Engineer: Brian Glasheen 907-545-1144 Production Engineer: Marina Krysinski 1H-107 | 1H-107L1Dual Lateral Producer1H-107 | 1H-107L1Dual Lateral ProducerAs DrilledRKB = 93 AMSLAs DrilledRKB = 93 AMSL20'' 94# H40 Welded Insulated Conductor120'/120' TVDCemented to Surface20'' 94# H40 Welded Insulated Conductor120'/120' TVDCemented to SurfaceProduction Tubing4-1/2'' 12.6# L80 H563Production Tubing4-1/2'' 12.6# L80 H563Intermediate Casing9-5/8'' 40# L80 H56310113'/3893' TVDIntermediate Casing9-5/8'' 40# L80 H56310113'/3893' TVDSLZXP LTP8982'/3664' TVDSLZXP LTP8982'/3664' TVDWindow Top Bottom 9237'-9254' MDWindow Top Bottom 9237'-9254' MDBaker RAM L5 Junction, 13Cr-80 Dual Seal Module, 9221'/ 3741' TVD RAM Hanger, 9225'/ 3742' TVDSealbore Diverter, 9230'/ 3744' TVD Baker RAM L5 Junction, 13Cr-80 Dual Seal Module, 9221'/ 3741' TVD RAM Hanger, 9225'/ 3742' TVDSealbore Diverter, 9230'/ 3744' TVD MLZXP LTP9299'/3767' TVDMLZXP LTP9299'/3767' TVDIntermediate TOC (25% washout)3479'/2860' TVDIntermediate TOC (25% washout)3479'/2860' TVDMain Bore: 1H-1074-1/2'' 12.6# 13CR-80 JFE BEAR16255'/3996' TVD6-3/4'' Production Hole16269'/3996' TVDMain Bore: 1H-1074-1/2'' 12.6# 13CR-80 JFE BEAR16255'/3996' TVD6-3/4'' Production Hole16269'/3996' TVDUpper Lateral: 1H-107L14-1/2'' 12.6# 13CR-80 JFE BEAR16126'/3926' TVD6-3/4'' Production Hole16163'/3925' TVDUpper Lateral: 1H-107L14-1/2'' 12.6# 13CR-80 JFE BEAR16126'/3926' TVD6-3/4'' Production Hole16163'/3925' TVDUGNU C 5035'/3081' TVDUGNU C 5035'/3081' TVDWEST SAK B 10042'/3899' TVDWEST SAK B 10042'/3899' TVDWEST SAK D 9598'/3846' TVDWEST SAK D 9598'/3846' TVDSurface Casing13-3/8'' 68# L80 H5631793'/1763' TVDCemented to SurfaceSurface Casing13-3/8'' 68# L80 H5631793'/1763' TVDCemented to SurfaceBaker Excluder 107 um Open Hole Standalone Screens | TAM 6.38" OD Water Swell Packer | Davis Lynch Shoe Baker Excluder 107 um Open Hole Standalone Screens | TAM 6.38" OD Water Swell Packer | Davis Lynch Shoe Baker Excluder 107 um Open Hole Standalone Screens | TAM 6.38" OD Water Swell Packer | Davis Lynch Shoe Baker Excluder 107 um Open Hole Standalone Screens | TAM 6.38" OD Water Swell Packer | Davis Lynch Shoe Upper Completion1. SLB 1.0" KBMG Gas Lift Mandrel (x2)2. HAL Single Gauge Mandrel3. Baker AccessESP Assembly4. SLB CMU Sliding Sleeve (3.813" X profile)5. HAL Chemical Injection Mandrel, with 13Cr-80 JFE Bear bottom pup joint6. 13Cr-80 Baker Locator, HAL Mule Shoe, and Seal AssemblyUpper Completion1. SLB 1.0" KBMG Gas Lift Mandrel (x2)2. HAL Single Gauge Mandrel3. Baker AccessESP Assembly4. SLB CMU Sliding Sleeve (3.813" X profile)5. HAL Chemical Injection Mandrel, with 13Cr-80 JFE Bear bottom pup joint6. 13Cr-80 Baker Locator, HAL Mule Shoe, and Seal Assembly 1H-107 Proposed RWO Schematic Description Set Depth MD Set Depth TVD OD ID Weight (lbs)Grade Top Conn Conductor 120 120 20 19.12 78.67 H40 Weld Surface 1793 1762.9 13.375 12.42 68 L-80 Hydril 563 Intermediate 10113 3902.8 9.625 8.84 40 L80 Hydril 563 Mainbore Liner 16255 3996.1 4.5 3.96 12.6 13Cr-80 JFEBear L1 Liner 16126 3926.4 4.5 3.96 12.6 13Cr-80 JFEBear Tubing 9000 3670.4 4.5 3.96 12.6 L-80 Hydril 563 Surface Casing: 1,793' RKB Conductor: Perfs Proposed Completion: 4 1/2" 12.6# L-80 HYD563 Tubing to Surface 4-1/2" x 1" GLMs @ TBD 4-1/2" Gauge and Mandrel w/ 1/4" TEC 4-1/2" AccessESP Assembly w/Up Cable 4-1/2" NEXA Sliding Sleeve 4-1/2" Locator Seal Assembly @ 9,000' RKB Existing Completion: SLZXP LTP @ 8,982' RKB 190-47 SBE @ 9,004' RKB Baker RAM L5 Junction @ 9,221' RKB B Sand Lateral (Mainbore): 4-1/2" 12.6# 13Cr JFE Bear Casing with Baker Excluder Screens @ 16,255' RKBIntermediate Casing: 9-5/8" 40# L- 80 Hyd563 @ 10,113 D Sand Lateral (L1 Liner): 4-1/2" 12.6# 13Cr JFE Bear Casing with Baker Excluder Screens @ 16,126' RKB RAM L5 Junction Intermediate Casing Calculated TOC: 3,981' RKB Surface Casing TOC: Surface Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull ACP ISO, Shift Sleeves open, Set ESP 1H-107 3/26/2025 appleha Notes: General & Safety Annotation End Date Last Mod By Note: Chrome tubing below 8,939'famaj Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread Conductor 20 19.12 39.7 120.0 120.0 78.67 B Surface 13 3/8 12.42 39.5 1,793.0 1,762.9 68.00 L-80 H563 Seal Bore Diverter 9.63 7.76 9,230.1 9,333.4 3,777.6 29.70 13Cr-80 N/A Intermediate 9 5/8 8.84 38.2 10,112.7 3,902.8 40.00 L-80 Hydril 563 Main bore Screen liner 4 1/2 3.96 9,298.7 16,254.5 3,996.1 12.60 13CR-80 JFEBear Main Bore Dual string module 3 1/2 2.99 8,982.1 9,253.3 3,752.2 9.20 13Cr-80 VamTop Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth 9,000.3 Set Depth 3,670.4 String Max No 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.9 36.9 0.00 Hanger 13.475 Streamflo hanger 4" H BPV, 6.25" acme lift threads - S/N StreamF lo DMLX 3.900 2,840.0 2,582.9 54.09 Mandrel 4.500 4-1/2" x 1" KBMG-1 GLM S/N 24190-09 SLB 4.5" x 1" KBMG 3.865 6,923.1 3,339.2 82.15 Mandrel 4.500 4-1/2" x 1" KBMG-1 GLM S/N 24190-05 SLB 4.5" x 1" KBMG 3.865 8,361.3 3,532.4 82.40 Gauge / Pump Sensor 6.077 HES Opsis Gauge mandrel w/ Downhole gauge, 4-1/2" H563, L80 HES 3.919 8,465.5 3,546.2 82.42 Sliding Sleeve 5.500 5-1/2" GV CMD Sliding sleeve 4 1/2" Vamtop Box x 5 1/2", 23#, Vam FJL Box ************ OPENED 3/23/25*************** Access ESP Sliding Sleeve 3.910 8,471.8 3,547.1 82.43 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,476.6 3,547.7 82.43 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,478.3 3,547.9 82.43 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,483.1 3,548.5 82.43 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,484.9 3,548.8 82.44 Motor Shroud 5.500 Motor Shroud, 5 1/2" Vam FJL Box x Pin Access ESP 3.894 8,489.7 3,549.4 82.44 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 4.548 8,491.4 3,549.6 82.44 Motor Shroud 5.500 Motor Shroud, 5 1/2" Vam FJL Box x Pin Access ESP 4.548 8,496.3 3,550.3 82.44 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,498.0 3,550.5 82.44 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,502.9 3,551.1 82.45 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,504.6 3,551.4 82.45 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,509.4 3,552.0 82.45 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,511.2 3,552.2 82.45 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,515.9 3,552.9 82.46 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,517.7 3,553.1 82.46 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,522.5 3,553.7 82.46 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,524.3 3,554.0 82.43 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,530.6 3,554.8 82.25 Annular Connection Port 5.950 Ann Connection Port, 5", 18# Vam FJL Box x 4 1/2" 12.6# Vamtop Box Access ESP 3.860 8,554.2 3,558.1 81.60 Profile Sub 4.500 B-Profile, 4 1/2", 12.6#, L-80 Vamtop Box x Box Access ESP 3.913 8,567.7 3,560.1 81.22 No-go nipple 5.000 No-Go, 4 1/2" 12.6# Vamtop Box x 4 1/2" Hyd 563 Box 3.805 8,873.3 3,630.1 72.37 Sliding Sleeve 5.490 CMU Sliding sleeve, 3.813" X Profile, 4-1/2", 12.6#, L80, H563 ******OPENED 3/22/25************ Camco NEXA CMU 3.813 8,939.1 3,650.7 71.39 Mandrel 5.600 HES Chemical injection mandrel, 4- 1/2" 12.6#, L80, H563 HES 4.330 8,999.5 3,670.1 71.11 Locator 5.190 Baker Locater 13Cr-80 3.880 9,000.3 3,670.4 71.10 Spacer tubes 13Cr-80 (10.68) 5.190 9,000.3 3,670.4 71.10 Baker Seal assembly 5.190 Baker 192-47 Seal assemblyw/ 3' of seals (3.18) 9,000.3 3,670.4 71.10 Mule Shoe Guide 5.190 Halliburton Self Aligning mule shoe guide (3.99) MULTIPLE LATERALS, 1H-107, 3/31/2025 12:44:56 PM Vertical schematic (actual) Main bore Screen liner; 9,298.7- 16,254.5 Float Shoe; 16,251.8-16,254.5 Casing Jts; 16,212.2-16,251.8 Drillable Pack Off Sub; 16,201.4- 16,202.6 Casing - Production Pup; 16,191.8-16,201.4 Casing-Screen; 15,476.3- 16,191.8 Packer - Swell 1; 15,456.6- 15,476.3 Casing-Screen; 14,741.0- 15,456.6 Packer - Swell 2; 14,721.3- 14,741.0 Packer - Swell 3; 14,224.4- 14,244.2 Casing-Screen; 13,072.0- 14,224.4 Packer - Swell 4; 13,052.3- 13,072.0 Casing-Screen; 10,470.6- 13,052.3 Packer - Swell 5; 10,450.9- 10,470.6 Packer - Swell 6; 10,311.3- 10,331.1 Casing-Screen; 10,113.1- 10,311.3 Intermediate; 38.2-10,112.7 Float Shoe; 10,109.6-10,112.7 Float Collar; 10,021.5-10,024.2 Casing - Production Pup; 9,393.5-9,396.6 XO Reducing; 9,392.0-9,393.5 Casing Jts; 9,352.3-9,392.0 XO Reducing; 9,348.5-9,352.3 C-2 Knock Out Isolation Valve; 9,346.2-9,348.5 KOIV Isolation Tool; 9,343.1- 9,346.2 XO Enlarging; 9,336.4-9,343.1 Seal Bore Diverter; 9,230.1- 9,333.4 Shoe - Mule; 9,330.1-9,333.4 XO Reducing; 9,325.2-9,326.7 Anchor; 9,311.7-9,314.0 Liner Hanger; 9,298.7-9,325.2 Anchor; 9,307.1-9,311.7 Nipple; 9,286.1-9,287.4 Main Bore Dual string module; 8,982.1-9,253.3 Seal Assembly; 9,233.9-9,253.3 L1 Screen Liner; 9,225.5- 16,125.6 L1 Dual String module; 8,982.1- 9,267.1 Seal Assembly; 9,233.9-9,267.1 Hanger; 9,233.1-9,262.3 Dual Seal Module; 9,228.0- 9,233.9 Dual Seal Module; 9,228.0- 9,233.9 Hanger; 9,225.5-9,233.1 Dual Seal Module; 9,201.5- 9,228.0 Dual Seal Module; 9,201.5- 9,228.0 Nipple - XN; 9,189.0-9,190.3 Nipple - XN; 9,138.6-9,139.9 Swivel; 9,126.3-9,128.8 Swivel; 9,122.0-9,124.6 Selective Re-entry Tool; 9,088.5- 9,108.5 Selective Re-entry Tool; 9,088.4- 9,108.5 Swivel; 9,074.3-9,078.0 Swivel; 9,074.3-9,078.0 XO Threads; 9,053.0-9,054.6 XO Threads; 9,052.9-9,054.6 FLCV; 9,035.6-9,042.4 FLCV; 9,035.5-9,042.4 SBR; 9,005.1-9,024.8 SBR; 9,005.0-9,024.8 PACKER ; 8,982.1-9,003.7 PACKER - LINER; 8,982.1- 9,003.6 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 No-go nipple; 8,567.7 Profile Sub; 8,554.2 Annular Connection Port; 8,530.6 Motor Shroud; 8,524.3 Motor Centralizer; 8,522.5 Motor Shroud; 8,517.7 Motor Centralizer; 8,515.9 Motor Shroud; 8,511.2 ESP MOTOR; 8,482.0 Motor Centralizer; 8,509.4 Motor Shroud; 8,504.6 Motor Centralizer; 8,502.8 Motor Shroud; 8,498.0 Motor Centralizer; 8,496.3 Motor Shroud; 8,491.4 Motor Centralizer; 8,489.7 Motor Shroud; 8,484.9 Motor Centralizer; 8,483.1 Motor Shroud; 8,478.3 Motor Centralizer; 8,476.6 Motor Shroud; 8,471.8 Sliding Sleeve; 8,465.5 ESP; 8,435.0 RBP; 8,428.9 Gauge / Pump Sensor; 8,361.3 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 6,923.1 Annular Fluid - Saltwater/Brine; 2,839.0-9,233.0; 10/5/2024 Mandrel; 2,840.0 Surface; 39.5-1,793.0 Float Shoe; 1,789.4-1,793.0 Annular Fluid - Diesel; 36.0- 2,839.0; 10/5/2024 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Casing Jts; 39.7-120.0 Casing Hanger; 39.5-40.2 Casing Hanger; 38.2-38.8 Hanger; 36.9 KUP PROD KB-Grd (ft) 39.50 RR Date 10/5/2024 Other Elev 1H-107 ... TD Act Btm (ftKB) 16,269.0 Well Attributes Field Name Wellbore API/UWI 500292379500 Wellbore Status PROD Max Angle & MD Incl (°) 92.92 MD (ftKB) 15,635.59 WELLNAME WELLBORE Annotation End DateH2S (ppm)DateComment Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,428.9 3,541.4 82.40 RBP 4.5" P2P PACKER, HANGOFF XO, STANDING VALVE WITH CHECK BALL AND SEAL STINGER, STUNG INTO TOP OF PUMP. CPP4 5036 3/26/2025 2.000 8,435.0 3,542.2 82.40 ESP 53.20' SUMMIT DUAL STAGE PUMP, 380, 67 STG, SF5800, T52. 3/25/2025 8,482.0 3,548.4 82.43 ESP MOTOR 57' ACCESS ESP 250 HP 4 POLE PPM MOTOR. 3/25/2025 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,840.0 2,582.9 54.09 1 GAS LIFT DMY BK 1 3/21/2025 SLB KBMG 6,923.1 3,339.2 82.15 2 GAS LIFT SOV BK 1 3/21/2025 2400#SLB KBMG Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,982.1 3,664.5 71.18 PACKER 9.625 Baker SLZXP w/ HD 10' ext, 9- 5/8" x 7" 29# H563 pin down 13 Cr -80 TOL xxxx' Baker SLZXP 7.380 9,003.7 3,671.5 71.10 XO Threads 7.000 Crossover sub, 7" 26# H563 x 5- 1/2" 15.5# H563 pin 13Cr-80 4.890 9,005.1 3,672.0 71.10 SBR 5.500 Baker 190-47 Seal bore, 5-1/2" 15.5# H563 B x P, 13Cr-80 Baker SBE 4.750 9,033.9 3,681.3 71.07 XO Threads 7.000 Crossover sub, 5-1/2" H563 x 7" H563, 13Cr-80 4.950 9,035.6 3,681.8 71.07 FLCV 7.000 7" FLCV, 7" H563 BxP 13Cr-80 (Locked open by pressuring up, sheared @ 2250 PSI, on 10/13/24) Baker 4.570 9,042.4 3,684.1 71.06 XO Threads 7.000 Crossover sub, 7" H563 x 5-1/2" H563, 13Cr-80 4.950 9,053.0 3,687.5 71.05 XO Threads 5.500 Crossover sub, 5-1/2" H563 x 4- 1/2" H563, 13Cr-80 Baker 3.850 9,054.6 3,688.0 71.05 XO Threads 4.500 Crossover sub, 4-1/2" H563 x 4- 1/2" VamTop, 13Cr-80 3.850 9,074.3 3,694.4 71.03 Swivel 4.500 Telescoping swivel sub, 4-1/2" VamTop, 13Cr-80, 24" Stroke Baker 3.870 9,088.5 3,699.0 71.02 Selective Re- entry Tool 4.500 Selective re-entry tool (MB and L1), 4-1/2" VT Box x (2) 3-1/2" VT box down Baker SRT 3.740 9,122.0 3,709.9 71.09 Swivel 3.500 Swivel Sub (mainbore) 3-1/2" 9.2#, VamTop BxP, 13Cr-80 Baker 2.960 9,138.7 3,715.3 71.13 Nipple - XN 3.500 2.813" XN, WITH A 2.75" NO-GO (mainbore), 3-1/2" 9.2# VamTop 13Cr-80 HES XN 2.750 9,183.0 3,729.6 71.22 XO Threads 3.500 Main bore XO 3-1/2" VT x 3.220" 7.9# SSDS-8 Pin 2.700 9,230.1 3,744.8 71.27 Window 9.630 Baker Seal Bore diverter, L5. Pos #1, 4-1/2" H563 pin (6.75' above TOW) 13Cr Baker RAM L5 SBD L1 7.760 9,257.8 3,753.6 71.30 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" H563 x JFE Bear 13Cr-80 3.900 9,286.1 3,762.7 71.38 Nipple 4.500 No Go sub w/ 2.6" Tapered ID, 4- 1/2" JFE Bear 13Cr-80 Baker No Go 2.600 9,287.4 3,763.1 71.39 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" JFE Bear x H563, 13Cr-80 3.910 9,307.1 3,769.4 71.54 Anchor 7.300 RAM ML Production Anchor (120k snap) 4-1/2" 12.6# 13Cr-80 above collet Baker RAM XL 3.910 9,311.7 3,770.8 71.57 Anchor 6.250 RAM ML Production Anchor (120k snap) 4-1/2" 12.6# 13Cr-80 below collet Baker RAM XL 3.910 9,314.0 3,771.6 71.59 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" H563 x STL pin, 4-1/2" 12.6#, 13Cr-80 3.890 9,325.2 3,775.1 71.67 XO Reducing 7.650 Baker 4.900 9,336.4 3,778.6 71.75 XO Enlarging 5.500 Baker 4.890 9,343.1 3,780.7 71.80 KOIV Isolation Tool 8.030 Baker KOIV 5.150 9,346.2 3,781.7 71.82 C-2 Knock Out Isolation Valve 7.000 C-2 Knock Out Isolation Valve Baker 6.120 9,348.6 3,782.4 71.84 XO Reducing 5.500 Baker 4.900 9,392.0 3,795.7 72.62 XO Reducing 4.500 3.958 10,311.4 3,906.4 90.85 Packer - Swell 6 4.500 TAM 3.958 10,450.9 3,904.1 91.10 Packer - Swell 5 4.500 TAM 3.958 13,052.3 3,941.2 87.25 Packer - Swell 4 4.500 TAM 3.958 14,224.4 3,986.8 88.39 Packer - Swell 3 4.500 TAM 3.958 14,721.3 4,012.0 87.34 Packer - Swell 2 4.500 TAM 3.958 15,456.6 4,014.1 91.18 Packer - Swell 1 4.500 TAM 3.958 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 39.7 1,793.0 39.7 1,762.9 Surface String Cement Pump 100 BBLS 10.9 PPG mud push, Pump 308 BBLS 11 PPG lead cement, see mud push at surface 280 BBLS away into lead, pump 71 BBLS 15.8 PPG tail cement, pump 20 BBLS H2O, chase with 232 BBLS 9.6 PPG spud mud, see 11.0 PPG lead cement at surface at 180 BBLS into Displacement, bump plugs, check floats, floats hold. 8/20/2024 MULTIPLE LATERALS, 1H-107, 3/31/2025 12:44:59 PM Vertical schematic (actual) Main bore Screen liner; 9,298.7- 16,254.5 Float Shoe; 16,251.8-16,254.5 Casing Jts; 16,212.2-16,251.8 Drillable Pack Off Sub; 16,201.4- 16,202.6 Casing - Production Pup; 16,191.8-16,201.4 Casing-Screen; 15,476.3- 16,191.8 Packer - Swell 1; 15,456.6- 15,476.3 Casing-Screen; 14,741.0- 15,456.6 Packer - Swell 2; 14,721.3- 14,741.0 Packer - Swell 3; 14,224.4- 14,244.2 Casing-Screen; 13,072.0- 14,224.4 Packer - Swell 4; 13,052.3- 13,072.0 Casing-Screen; 10,470.6- 13,052.3 Packer - Swell 5; 10,450.9- 10,470.6 Packer - Swell 6; 10,311.3- 10,331.1 Casing-Screen; 10,113.1- 10,311.3 Intermediate; 38.2-10,112.7 Float Shoe; 10,109.6-10,112.7 Float Collar; 10,021.5-10,024.2 Casing - Production Pup; 9,393.5-9,396.6 XO Reducing; 9,392.0-9,393.5 Casing Jts; 9,352.3-9,392.0 XO Reducing; 9,348.5-9,352.3 C-2 Knock Out Isolation Valve; 9,346.2-9,348.5 KOIV Isolation Tool; 9,343.1- 9,346.2 XO Enlarging; 9,336.4-9,343.1 Seal Bore Diverter; 9,230.1- 9,333.4 Shoe - Mule; 9,330.1-9,333.4 XO Reducing; 9,325.2-9,326.7 Anchor; 9,311.7-9,314.0 Liner Hanger; 9,298.7-9,325.2 Anchor; 9,307.1-9,311.7 Nipple; 9,286.1-9,287.4 Main Bore Dual string module; 8,982.1-9,253.3 Seal Assembly; 9,233.9-9,253.3 L1 Screen Liner; 9,225.5- 16,125.6 L1 Dual String module; 8,982.1- 9,267.1 Seal Assembly; 9,233.9-9,267.1 Hanger; 9,233.1-9,262.3 Dual Seal Module; 9,228.0- 9,233.9 Dual Seal Module; 9,228.0- 9,233.9 Hanger; 9,225.5-9,233.1 Dual Seal Module; 9,201.5- 9,228.0 Dual Seal Module; 9,201.5- 9,228.0 Nipple - XN; 9,189.0-9,190.3 Nipple - XN; 9,138.6-9,139.9 Swivel; 9,126.3-9,128.8 Swivel; 9,122.0-9,124.6 Selective Re-entry Tool; 9,088.5- 9,108.5 Selective Re-entry Tool; 9,088.4- 9,108.5 Swivel; 9,074.3-9,078.0 Swivel; 9,074.3-9,078.0 XO Threads; 9,053.0-9,054.6 XO Threads; 9,052.9-9,054.6 FLCV; 9,035.6-9,042.4 FLCV; 9,035.5-9,042.4 SBR; 9,005.1-9,024.8 SBR; 9,005.0-9,024.8 PACKER ; 8,982.1-9,003.7 PACKER - LINER; 8,982.1- 9,003.6 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 No-go nipple; 8,567.7 Profile Sub; 8,554.2 Annular Connection Port; 8,530.6 Motor Shroud; 8,524.3 Motor Centralizer; 8,522.5 Motor Shroud; 8,517.7 Motor Centralizer; 8,515.9 Motor Shroud; 8,511.2 ESP MOTOR; 8,482.0 Motor Centralizer; 8,509.4 Motor Shroud; 8,504.6 Motor Centralizer; 8,502.8 Motor Shroud; 8,498.0 Motor Centralizer; 8,496.3 Motor Shroud; 8,491.4 Motor Centralizer; 8,489.7 Motor Shroud; 8,484.9 Motor Centralizer; 8,483.1 Motor Shroud; 8,478.3 Motor Centralizer; 8,476.6 Motor Shroud; 8,471.8 Sliding Sleeve; 8,465.5 ESP; 8,435.0 RBP; 8,428.9 Gauge / Pump Sensor; 8,361.3 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 6,923.1 Annular Fluid - Saltwater/Brine; 2,839.0-9,233.0; 10/5/2024 Mandrel; 2,840.0 Surface; 39.5-1,793.0 Float Shoe; 1,789.4-1,793.0 Annular Fluid - Diesel; 36.0- 2,839.0; 10/5/2024 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Casing Jts; 39.7-120.0 Casing Hanger; 39.5-40.2 Casing Hanger; 38.2-38.8 Hanger; 36.9 KUP PROD 1H-107 ... WELLNAME WELLBORE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 3,981.0 10,112.0 2,942.8 3,902.8 Intermediate String 1 Cement 8/29/2024 MULTIPLE LATERALS, 1H-107, 3/31/2025 12:45:01 PM Vertical schematic (actual) Main bore Screen liner; 9,298.7- 16,254.5 Float Shoe; 16,251.8-16,254.5 Casing Jts; 16,212.2-16,251.8 Drillable Pack Off Sub; 16,201.4- 16,202.6 Casing - Production Pup; 16,191.8-16,201.4 Casing-Screen; 15,476.3- 16,191.8 Packer - Swell 1; 15,456.6- 15,476.3 Casing-Screen; 14,741.0- 15,456.6 Packer - Swell 2; 14,721.3- 14,741.0 Packer - Swell 3; 14,224.4- 14,244.2 Casing-Screen; 13,072.0- 14,224.4 Packer - Swell 4; 13,052.3- 13,072.0 Casing-Screen; 10,470.6- 13,052.3 Packer - Swell 5; 10,450.9- 10,470.6 Packer - Swell 6; 10,311.3- 10,331.1 Casing-Screen; 10,113.1- 10,311.3 Intermediate; 38.2-10,112.7 Float Shoe; 10,109.6-10,112.7 Float Collar; 10,021.5-10,024.2 Casing - Production Pup; 9,393.5-9,396.6 XO Reducing; 9,392.0-9,393.5 Casing Jts; 9,352.3-9,392.0 XO Reducing; 9,348.5-9,352.3 C-2 Knock Out Isolation Valve; 9,346.2-9,348.5 KOIV Isolation Tool; 9,343.1- 9,346.2 XO Enlarging; 9,336.4-9,343.1 Seal Bore Diverter; 9,230.1- 9,333.4 Shoe - Mule; 9,330.1-9,333.4 XO Reducing; 9,325.2-9,326.7 Anchor; 9,311.7-9,314.0 Liner Hanger; 9,298.7-9,325.2 Anchor; 9,307.1-9,311.7 Nipple; 9,286.1-9,287.4 Main Bore Dual string module; 8,982.1-9,253.3 Seal Assembly; 9,233.9-9,253.3 L1 Screen Liner; 9,225.5- 16,125.6 L1 Dual String module; 8,982.1- 9,267.1 Seal Assembly; 9,233.9-9,267.1 Hanger; 9,233.1-9,262.3 Dual Seal Module; 9,228.0- 9,233.9 Dual Seal Module; 9,228.0- 9,233.9 Hanger; 9,225.5-9,233.1 Dual Seal Module; 9,201.5- 9,228.0 Dual Seal Module; 9,201.5- 9,228.0 Nipple - XN; 9,189.0-9,190.3 Nipple - XN; 9,138.6-9,139.9 Swivel; 9,126.3-9,128.8 Swivel; 9,122.0-9,124.6 Selective Re-entry Tool; 9,088.5- 9,108.5 Selective Re-entry Tool; 9,088.4- 9,108.5 Swivel; 9,074.3-9,078.0 Swivel; 9,074.3-9,078.0 XO Threads; 9,053.0-9,054.6 XO Threads; 9,052.9-9,054.6 FLCV; 9,035.6-9,042.4 FLCV; 9,035.5-9,042.4 SBR; 9,005.1-9,024.8 SBR; 9,005.0-9,024.8 PACKER ; 8,982.1-9,003.7 PACKER - LINER; 8,982.1- 9,003.6 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 No-go nipple; 8,567.7 Profile Sub; 8,554.2 Annular Connection Port; 8,530.6 Motor Shroud; 8,524.3 Motor Centralizer; 8,522.5 Motor Shroud; 8,517.7 Motor Centralizer; 8,515.9 Motor Shroud; 8,511.2 ESP MOTOR; 8,482.0 Motor Centralizer; 8,509.4 Motor Shroud; 8,504.6 Motor Centralizer; 8,502.8 Motor Shroud; 8,498.0 Motor Centralizer; 8,496.3 Motor Shroud; 8,491.4 Motor Centralizer; 8,489.7 Motor Shroud; 8,484.9 Motor Centralizer; 8,483.1 Motor Shroud; 8,478.3 Motor Centralizer; 8,476.6 Motor Shroud; 8,471.8 Sliding Sleeve; 8,465.5 ESP; 8,435.0 RBP; 8,428.9 Gauge / Pump Sensor; 8,361.3 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 6,923.1 Annular Fluid - Saltwater/Brine; 2,839.0-9,233.0; 10/5/2024 Mandrel; 2,840.0 Surface; 39.5-1,793.0 Float Shoe; 1,789.4-1,793.0 Annular Fluid - Diesel; 36.0- 2,839.0; 10/5/2024 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Casing Jts; 39.7-120.0 Casing Hanger; 39.5-40.2 Casing Hanger; 38.2-38.8 Hanger; 36.9 KUP PROD 1H-107 ... WELLNAME WELLBORE 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: Convert to GL 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 12629'feet 8429' feet true vertical 3996' feet None feet Effective Depth measured 8429'feet 8982'feet true vertical 3541' feet 3665' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-3/4" 4-1/2" L-80 8539' MD 9000' MD 3556' TVD 3670' TVD Packers and SSSV (type, measured and true vertical depth) 8982' MD 3664' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 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: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker SLZXP Natalie Dye Natalie.B.Dye@conocophillips.com (907) 265-1027Senior Production Engineer None None Main Bore Dual String Module 271' Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 5296 Gas-Mcf MD 228 Size 120' 134 11073556 0 2250 383 Intermediate 20" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 224-092 50-029-23795-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025636, ADL0025637, ADL0025639 Kuparuk River Oil Field/ West Sak Oil Pool KRU 1H-107 80' measured TVD 9-5/8" Plugs Junk measured Length measured true vertical Packer Burst Collapse Seal Bore Diverter Main Bore Screen Liner 10075' 103' 6956' Casing 3903' 3778' 4-1/2" 10113' 9333' 16255' 3996' 1754' 120'Conductor Surface 3-1/2" 9253' 3752' 1793' 1763' 9.63" 13-3/8" Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Gavin Gluyas at 1:09 pm, Sep 23, 2025 Natasha Dye Digitally signed by Natasha Dye Date: 2025.09.23 10:24:44 -08'00' RBDMS JSB 092525 J.Lau 11/5/25 DTTMSTART JOBTYP SUMMARYOPS 8/22/2025 OPTIMIZE WELL LATCH AND RETRIEVE P2P PACKOFF ASSEMBLY AT 8428'. LATCH AND RETRIEVE ESP PUMP AT 8432'. PUMP OFF ESP PUMP AND LEAVE AT 2700' FOR SLU RECOVERY. ACCESS & SUMMIT REPS TEST ESP MOTOR AND MOTOR FAILS THE NO-LOAD TEST. STAND BACK COIL UNIT TO ALLOW SLU ACCESS TO THE WELL FOR RETRIEVAL OF ESP PUMP. JOB IN PROGRESS. 8/22/2025 OPTIMIZE WELL PULL SUMMIT ESP PUMP @ 3940' RKB, STANDBY FOR CTU TO PULL MOTOR. IN PROGRESS 8/23/2025 OPTIMIZE WELL LATCH AND RETRIEVE ESP MOTOR AT 8485'. ACCESS REPS TEST ESP POWER CABLE: 1 LEG GROUNDED OUT, 1 LEG WEAK AT 118 MEGA OHMS & 1 STRONG LEG AT 5.62 GIGA OHMS. PUMP OFF AND DROP MOTOR @ 2400' FOR SLU RECOVERY. STAND BACK COIL UNIT TO ALLOW SLU ACCESS TO WELL. JOB IN PROGRESS. 8/23/2025 OPTIMIZE WELL PULLED ACCESS MOTOR @ 3780' RKB, JOB IN PROGRESS 8/24/2025 OPTIMIZE WELL CLOSE NEXA CMU AT 8873'. SHIFTING TOOL IS NOT SHEARED AND CONFIRMS CLOSED SLEEVE. CHANGE PACK OFF. JOB IN PROGRESS. 8/25/2025 OPTIMIZE WELL SET ISO SLEEVE AT 8530'. CLOSE ACCESS GV CMD AT 8465'. TOOL IS NOT SHEARED CONFIRMING CMD IS CLOSED. PUMP TO IA WITH 66 BBL DIESEL FOR PRESSURE TEST, COMMUNICATE TO TUBING. MAKE SECOND RUN TO CLOSE CMD AT 8465' AND UNABLE TO LOCATE, TOOL IS NOT SHEARED RE-CONFIRMING CMD IS CLOSED. CALL INTEGRITY ENGINEER. SHOOT FLUID LEVELS WITH IA AT 294' AND TUBING AT 252'. PUMP 46 BBL TO IA. INJECTING DIESEL 2.0 BPM AT 300 PSI. SDFN. JOB IN PROGRESS 8/26/2025 OPTIMIZE WELL SPINNER LOG TO 8900'. DOWNLOAD MEMORY SUB - GOOD DATA. SHEAR OUT VALVE AT 6923' IS SHEARED. PUMP 150 BBL 1% 776 SLICK DIESEL TO TUBING TO CONDITION WELL FOR SLICKLINE OPERATIONS. READY FOR SLICKLINE. JOB IN PROGRESS. 8/27/2025 OPTIMIZE WELL MAKE SEVERAL ATTEMPTS TO SET SS CATCHER UNDER STA #2, RUN DOGLESS GS TO ACP SLEEVE @ 8530' RKB, DEPLOY FLAT BOTTOM CATCHER AND CHASE BELOW STA #2, PULL SOV FROM STA #2... IN PROGRESS. 8/28/2025 OPTIMIZE WELL SET OV IN STA #2 @ 6923' RKB. REPLACE DMY W/ GLV @ 2840' RKB. PULL CATCHER @ 6972' SLM. JOB COMPLETE. 8/29/2025 SUPPORT OTHER OPERATIONS (PRE-RWO) UPPER T POT (PASS), UPPER T PPPOT (FAIL), LOWER T POT (PASS), LOWER T PPPOT (PASS), IC PO (PASS), IC PPPOT (PASS) 1H-107 Convert to GasLift Summary of Operations Last Rev Reason Last Mod ByWellboreEnd DateAnnotation praffer1H-107 9/18/2025Rev Reason: Install Access ESP motor and pump, Set PIIP Packoff Assembly Notes: General & Safety Last Mod ByEnd DateAnnotation famajNote: Chrome tubing below 8,939' Casing Strings Top (ftKB)ID (in)OD (in)Csg Des Set Depth (ftKB) Set Depth Top ThreadGradeWt/Len (lb/ft)(TVD) (ftKB) 78.6739.719.1220 120.0120.0Conductor B H56368.00 L-8039.512.4213 3/8 1,762.91,793.0Surface N/A29.70 13Cr-809,230.17.769.63 3,777.69,333.4Seal Bore Diverter Hydril 56340.00 L-8038.28.849 5/8 3,902.810,112.7Intermediate JFEBear12.60 13CR-809,298.73.964 1/2 3,996.116,254.5Main bore Screen liner Main Bore Dual string module VamTop3,752.2 9.20 13Cr-809,253.38,982.12.993 1/2 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.9 Set Depth… 9,015.0 Set Depth… 3,675.2 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl Item Des(°) OD Nominal (in)Make ModelCom Nominal ID (in) 13.475 Streamflo hanger 4" H BPV, 6.25"0.00 Hanger36.936.9 acme lift threads - S/N StreamF lo DMLX 3.900 4.500 4-1/2"x 1"KBMG-1 GLM53.94 Mandrel2,580.22,835.3 psi SOV,W/BEK Latch S/N 24190- 09 4.5"x 1"SLB KBMG 3.865 4.500 4-1/2"x 1"KBMG-1 GLM82.15 Mandrel3,338.56,918.4 DV&BK S/N 241-05 4.5"x 1"SLB KBMG 3.865 82.40 Gauge /Pump3,531.88,356.6 Sensor 6.077 HES Opsis Gauge mandrel w/ Downhole gauge,4-1/2"H563,L80 3.919HES 5.500 5-1/2"GV Sliding sleeve 4 1/2"82.42 Sliding Sleeve3,545.68,460.8 Vamtop Box x 5 1/2",23#,Vam FJL Box ((OPENED 9/14/25)) Access ESP Sliding Sleeve 3.910 5.500 Motor Shroud,5 1/2"23#Vam FJL82.42 Motor Shroud3,546.48,467.1 Pin x Pin Access ESP 4.548 82.43 Motor3,547.18,471.9 Centralizer 5.500 Motor Cenralizer,5 1/2"23#Vam FJL Box x Box Access ESP 3.894 5.500 Motor Shroud,5 1/2"23#Vam FJL82.43 Motor Shroud3,547.38,473.6 Pin x Pin Access ESP 4.548 82.43 Motor3,547.98,478.4 Centralizer 5.500 Motor Cenralizer,5 1/2"23#Vam FJL Box x Box Access ESP 3.893 5.500 Motor Shroud,5 1/2"Vam FJL Box x82.43 Motor Shroud3,548.28,480.2 Pin Access ESP 3.894 82.44 Motor3,548.88,485.0 Centralizer 5.500 Motor Cenralizer,5 1/2"23#Vam FJL Box x Box Access ESP 4.548 82.44 Motor Shroud3,549.08,486.8 5.500 Motor Shroud,5 1/2"Vam FJL Box x Pin Access ESP 4.548 82.44 Motor3,549.78,491.6 Centralizer 5.500 Motor Cenralizer,5 1/2"23#Vam FJL Box x Box Access ESP 3.894 82.44 Motor Shroud3,549.98,493.4 5.500 Motor Shroud,5 1/2"23#Vam FJL Pin x Pin Access ESP 4.548 82.44 Motor3,550.58,498.2 Centralizer 5.500 Motor Cenralizer,5 1/2"23#Vam FJL Box x Box Access ESP 3.893 82.44 Motor Shroud3,550.88,499.9 5.500 Motor Shroud,5 1/2"23#Vam FJL Pin x Pin Access ESP 4.548 82.45 Motor3,551.48,504.7 Centralizer 5.500 Motor Cenralizer,5 1/2"23#Vam FJL Box x Box Access ESP 3.894 82.45 Motor Shroud3,551.68,506.5 5.500 Motor Shroud,5 1/2"23#Vam FJL Pin x Pin Access ESP 4.548 82.45 Motor3,552.28,511.3 Centralizer 5.500 Motor Cenralizer,5 1/2"23#Vam FJL Box x Box Access ESP 3.894 5.500 Motor Shroud,5 1/2"23#Vam FJL82.45 Motor Shroud3,552.58,513.0 Pin x Pin Access ESP 4.548 3,553.1 82.46 Motor8,517.8 Centralizer 5.500 Motor Cenralizer,5 1/2"23#Vam FJL Box x Box Access ESP 3.894 5.500 Motor Shroud,5 1/2"23#Vam FJL82.46 Motor Shroud3,553.38,519.6 Pin x Pin Access ESP 4.548 82.38 Annular3,554.28,525.9 Connection Port 5.950 Ann Connection Port,5",18#Vam FJL Box x 4 1/2"12.6#Vamtop Box Access ESP 3.860 4.500 B-Profile,4 1/2",12.6#,L-80 Vamtop3,557.48,549.5 81.73 Profile Sub Box x Box Access ESP 3.913 5.000 No-Go,4 1/2"12.6#Vamtop Box x 481.35 No-go nipple3,559.48,563.0 1/2"Hyd 563 Box 3.805 5.490 CMU Sliding sleeve,3.813"X72.50 Sliding Sleeve3,628.68,868.6 Profile,4-1/2",12.6#,L80,H563 ((OPENED 9/15/25)) SlidingCamco Sleve w/ X-Profile P/N#381 NEXAX27 642, S/N#03 3.813 5.600 HES Chemical injection mandrel,4-71.42 Mandrel3,649.28,934.4 1/2"12.6#,L80,H563 ChemicaHES l Injection Mandrel, HES SAP# 1108136 4.330 MULTIPLE LATERARRLS,1H-107,8/23/2025 5:00:00 PM Vertical schematic (actual) Main bore Screen liner;9,298.7- 16,254.5 Intermediate;38.2-10,112.7 Seal Bore Diverter;9,230.1- 9,333.4 Main Bore Dual string module; 8,982.1-9,253.3 L1 Dual String module;8,982.1- 9,267.1 L1 Screen Liner;9,225.5- 16,125.6 Locator;8,999.5 XO Threads;8,993.3 Mandrel;8,939.1 Sliding Sleeve;8,873.3 Sliding Sleeve;8,465.5 Intermediate String 1 Cement; 3,981.0 ftffKB Mandrel;6,923.1 Mandrel;2,840.0 Surface;39.5-1,793.0 Surface String Cement;39.7 ftffKB Conductor;39.7-120.0 Hanger;36.9 KUP PROD KB-Grd (ftff) 39.50 RR Date 10/5/2024 Other Elev… 1H-107 ... TD Act Btm (ftffKB) 16,269.0 Well AtAAtributes Wellbore API/UWIFieldName 500292379500 Wellbore Status PROD Max Angle &MD Incl (°) 92.92 MD (ftffKB) 15,635.59 WELLBOREWELLNAME1H-107 End DateAnnotationH2S(ppm)DateComment Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,994.8 3,668.6 71.11 Locator 5.190 Baker Locater 13Cr-80 3.880 8,995.6 3,668.9 71.11 Seal Assembly 4.730 Baker 192-47 Seal assembly (1.54) Baker 3.958 9,007.8 3,672.8 71.10 Seal Assembly 4.730 Baker 192-47 Seal assemblyw/ 3' of seals (3.18) Baker 3.890 9,011.0 3,673.9 71.09 Wireline Guide 4.500 #REF! 3.890 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,418.8 3,540.1 82.40 RBP 4.5" P2P PACKER, HANGOFF XO, STANDING VALVE WITH CHECK BALL AND SEAL STINGER, STUNG INTO TOP OF PUMP. QUADC O PARAG ON II CPP4 5027 9/18/2025 2.000 8,424.6 3,540.8 82.40 ESP 53.21' SUMMIT DUAL STAGE PUMP, 380, 67 STG, SF5800, T52. SUMMIT 380, 67 STG, SF5800, TS2 14279 710/1 42797 11 9/18/2025 8,477.8 3,547.8 82.43 ESP MOTOR 57' ACCESS ESP, 400 HP, 4 POLE PPM MOTOR. ACCESS 400 HP 16739 871 9/16/2025 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,835.3 2,580.2 53.94 1 GAS LIFT GLV BK 1 1,600.0 8/28/2025 SLB KBMG 0.313 6,918.4 3,338.5 82.15 2 GAS LIFT OVBK 1 8/28/2025 SLB KBMG0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,982.1 3,664.5 71.18 PACKER 9.625 Baker SLZXP w/ HD 10' ext, 9- 5/8" x 7" 29# H563 pin down 13 Cr -80 TOL xxxx' Baker SLZXP 7.380 9,003.7 3,671.5 71.10 XO Threads 7.000 Crossover sub, 7" 26# H563 x 5- 1/2" 15.5# H563 pin 13Cr-80 4.890 9,005.1 3,672.0 71.10 SBR 5.500 Baker 190-47 Seal bore, 5-1/2" 15.5# H563 B x P, 13Cr-80 Baker SBE 4.750 9,033.9 3,681.3 71.07 XO Threads 7.000 Crossover sub, 5-1/2" H563 x 7" H563, 13Cr-80 4.950 9,035.63,681.8 71.07FLCV7.000 7" FLCV, 7" H563 BxP 13Cr-80 (Locked open by pressuring up, sheared @ 2250 PSI, on 10/13/24) Baker4.570 9,042.4 3,684.1 71.06 XO Threads 7.000 Crossover sub, 7" H563 x 5-1/2" H563, 13Cr-80 4.950 9,053.0 3,687.5 71.05 XO Threads 5.500 Crossover sub, 5-1/2" H563 x 4- 1/2" H563, 13Cr-80 Baker 3.850 9,054.6 3,688.0 71.05 XO Threads 4.500 Crossover sub, 4-1/2" H563 x 4- 1/2" VamTop, 13Cr-80 3.850 9,074.3 3,694.4 71.03 Swivel 4.500 Telescoping swivel sub, 4-1/2" VamTop, 13Cr-80, 24" Stroke Baker 3.870 9,088.5 3,699.0 71.02 Selective Re- entry Tool 4.500 Selective re-entry tool (MB and L1), 4-1/2" VT Box x (2) 3-1/2" VT box down Baker SRT 3.740 9,122.0 3,709.9 71.09 Swivel 3.500 Swivel Sub (mainbore) 3-1/2" 9.2#, VamTop BxP, 13Cr-80 Baker2.960 9,138.7 3,715.3 71.13 Nipple - XN 3.500 2.813" XN, WITH A 2.75" NO-GO (mainbore), 3-1/2" 9.2# VamTop 13Cr-80 HES XN 2.750 9,183.0 3,729.6 71.22 XO Threads 3.500 Main bore XO 3-1/2" VT x 3.220" 7.9# SSDS-8 Pin 2.700 9,230.13,744.8 71.27 Window 9.630 Baker Seal Bore diverter, L5. Pos #1, 4-1/2" H563 pin (6.75' above TOW) 13Cr Baker RAM L5 SBD L1 7.760 9,257.8 3,753.6 71.30 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" H563 x JFE Bear 13Cr-80 3.900 9,286.1 3,762.7 71.38 Nipple 4.500 No Go sub w/ 2.6" Tapered ID, 4- 1/2" JFE Bear 13Cr-80 BakerNo Go 2.600 9,287.4 3,763.1 71.39 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" JFE Bear x H563, 13Cr-80 3.910 9,307.1 3,769.4 71.54 Anchor 7.300 RAM ML Production Anchor (120k snap) 4-1/2" 12.6# 13Cr-80 above collet BakerRAM XL 3.910 9,311.7 3,770.8 71.57 Anchor 6.250 RAM ML Production Anchor (120k snap) 4-1/2" 12.6# 13Cr-80 below collet BakerRAM XL 3.910 9,314.03,771.6 71.59 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" H563 x STL pin, 4-1/2" 12.6#, 13Cr-80 3.890 9,325.2 3,775.1 71.67 XO Reducing 7.650 Baker 4.900 9,336.4 3,778.6 71.75 XO Enlarging 5.500 Baker 4.890 9,343.1 3,780.7 71.80 KOIV Isolation Tool 8.030 BakerKOIV 5.150 9,346.2 3,781.7 71.82 C-2 Knock Out Isolation Valve 7.000 C-2 Knock Out Isolation Valve Baker 6.120 9,348.6 3,782.4 71.84 XO Reducing 5.500 Baker 4.900 9,392.0 3,795.7 72.62 XO Reducing 4.500 3.958 10,311.4 3,906.4 90.85 Packer - Swell 6 4.500 TAM 3.958 10,450.9 3,904.1 91.10 Packer - Swell 5 4.500 TAM 3.958 13,052.3 3,941.2 87.25 Packer - Swell 4 4.500 TAM 3.958 14,224.4 3,986.8 88.39 Packer - Swell 3 4.500 TAM 3.958 14,721.3 4,012.0 87.34 Packer - Swell 2 4.500 TAM 3.958 15,456.6 4,014.191.18 Packer - Swell 1 4.500 TAM 3.958 MULTIPLE LATERALS, 1H-107, 8/23/2025 5:00:00 PM Vertical schematic (actual) Main bore Screen liner; 9,298.7- 16,254.5 Intermediate; 38.2-10,112.7 Seal Bore Diverter; 9,230.1- 9,333.4 Main Bore Dual string module; 8,982.1-9,253.3 L1 Dual String module; 8,982.1- 9,267.1 L1 Screen Liner; 9,225.5- 16,125.6 Locator; 8,999.5 XO Threads; 8,993.3 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 Sliding Sleeve; 8,465.5 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 6,923.1 Mandrel; 2,840.0 Surface; 39.5-1,793.0 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Hanger; 36.9 KUP PROD 1H-107 ... WELLNAME WELLBORE Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 39.7 1,793.0 39.7 1,762.9 Surface String Cement Pump 100 BBLS 10.9 PPG mud push, Pump 308 BBLS 11 PPG lead cement, see mud push at surface 280 BBLS away into lead, pump 71 BBLS 15.8 PPG tail cement, pump 20 BBLS H2O, chase with 232 BBLS 9.6 PPG spud mud, see 11.0 PPG lead cement at surface at 180 BBLS into Displacement, bump plugs, check floats, floats hold. 8/20/2024 3,981.0 10,112.0 2,942.8 3,902.8 Intermediate String 1 Cement 8/29/2024 MULTIPLE LATERALS, 1H-107, 8/23/2025 5:00:00 PM Vertical schematic (actual) Main bore Screen liner; 9,298.7- 16,254.5 Intermediate; 38.2-10,112.7 Seal Bore Diverter; 9,230.1- 9,333.4 Main Bore Dual string module; 8,982.1-9,253.3 L1 Dual String module; 8,982.1- 9,267.1 L1 Screen Liner; 9,225.5- 16,125.6 Locator; 8,999.5 XO Threads; 8,993.3 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 Sliding Sleeve; 8,465.5 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 6,923.1 Mandrel; 2,840.0 Surface; 39.5-1,793.0 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Hanger; 36.9 KUP PROD 1H-107 ... WELLNAME WELLBORE Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread L1 Screen Liner 4 1/2 3.96 9,225.5 16,125.6 3,926.4 12.60 13Cr-80 JFE Bear L1 Dual String module 3 1/2 2.99 8,982.1 9,267.1 3,756.2 9.20 13Cr-80 VamTop Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,003.63,671.5 71.10 XO Threads 7.000 Crossover sub, 7" 26# H563 x 5- 1/2" 15.5# H563 pin 13Cr-80 4.890 9,005.1 3,671.9 71.10 SBR 5.500 Baker 190-47 Seal bore, 5-1/2" 15.5# H563 B x P, 13Cr-80 Baker SBE 4.750 9,033.9 3,681.3 71.07 XO Threads 7.000 Crossover sub, 5-1/2" H563 x 7" H563, 13Cr-80 4.950 9,035.63,681.8 71.07FLCV7.000 7" FLCV, 7" H563 BxP 13Cr-80 Baker 4.570 9,042.4 3,684.0 71.06 XO Threads 7.000 Crossover sub, 7" H563 x 5-1/2" H563, 13Cr-80 4.950 9,052.9 3,687.5 71.05 XO Threads 5.500 Crossover sub, 5-1/2" H563 x 4- 1/2" H563, 13Cr-80 Baker 3.850 9,054.6 3,688.0 71.05 XO Threads 4.500 Crossover sub, 4-1/2" H563 x 4- 1/2" VamTop, 13Cr-80 3.850 9,074.3 3,694.4 71.03 Swivel 4.500 Telescoping swivel sub, 4-1/2" VamTop, 13Cr-80, 24" Stroke Baker 3.870 9,088.4 3,699.0 71.02 Selective Re- entry Tool 4.500 Selective re-entry tool (MB and L1), 4-1/2" VT Box x (2) 3-1/2" VT box down (1.34' from top to 3.74" ID) Baker SRT 3.740 9,126.3 3,711.3 71.10 Swivel 3.500 Swivel Sub (mainbore) 3-1/2" 9.2#, VamTop BxP, 13Cr-80 Baker2.960 9,189.0 3,731.5 71.22 Nipple - XN 3.500 2.813" XN WITH A 2.75" NO-GO (L1), 3-1/2" 9.2# VamTop 13Cr-80 HES XN 2.750 9,190.3 3,732.0 71.22 XO Threads 3.500 L1 XO 3-1/2" VT x 3.220" 7.9# SSDS-8 Pin 2.700 9,271.9 3,757.6 73.15 XO Reducing 5.500 Crossover Sub, 5-1/2" 15.5# H563 x 4-1/2", 12.6# JFE Bear, 13 Cr- 80 3.930 10,384.7 3,833.9 90.94 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #6 TAM FREECAP 5' 3.958 10,760.6 3,825.1 90.42 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #5 TAM FREECAP 5' 3.958 12,330.7 3,850.1 87.93 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #4 TAM FREECAP 5' 3.958 14,177.4 3,913.9 87.31 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #3 TAM FREECAP 5' 3.958 14,671.5 3,947.5 87.32 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #2 TAM FREECAP 5' 3.958 15,365.1 3,942.1 91.44 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #1 TAM FREECAP 5' 3.958 16,072.6 3,927.7 91.45 Drillable packoff bushing 4.500 Drillable Packoff Bushing, 4-1/2", 12.6#, 13Cr-80, JFE Bear BakerDPOB 3.958 MULTIPLE LATERALS, 1H-107L1, 8/23/2025 5:00:00 PM Vertical schematic (actual) L1 Screen Liner; 9,225.5- 16,125.6 L1 Dual String module; 8,982.1- 9,267.1 Main Bore Dual string module; 8,982.1-9,253.3 Seal Bore Diverter; 9,230.1- 9,333.4 Intermediate; 38.2-10,112.7 Locator; 8,999.5 XO Threads; 8,993.3 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 Sliding Sleeve; 8,465.5 Mandrel; 6,923.1 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 2,840.0 Surface; 39.5-1,793.0 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Hanger; 36.9 KUP PROD KB-Grd (ft) 39.50 RR Date 10/5/2024 Other Elev… 1H-107L1 ... TD Act Btm (ftKB) 16,163.0 Well Attributes Field Name Wellbore API/UWI 500292379560 Wellbore Status PROD Max Angle & MD Incl (°) 92.96 MD (ftKB) 10,145.72 WELLNAME WELLBORE Annotation End DateH2S (ppm)DateComment C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-09-14_23097_KRU_1H-107_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23097 KRU 1H-107 50-029-23795-00 Caliper Survey w/ Log Data 14-Sep-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 224-092 T40897 9/17/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.17 08:14:10 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-08-26_22235_KRU_1H-107_STPLeakDetectLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22235 KRU 1H-107 50-029-23795-00 STP Leak Detect Log 26-Aug-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 224-092 T40820 8/27/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.27 11:35:18 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 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?N/A Yes No 9. Property Designation (Lease Number): 10. Field: West Sak Oil Pool West Sak Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 16269'986 None Casing Collapse Conductor Surface Intermediate Seal Bore Diverter Main bore Screen Liner Main bore dual string module Packers and SSSV Type: 12. Attachments:Proposal Summary Wellbore schematic 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: 907-265-6049 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 9.63"9333'3778' 6956'4-1/2'16255'3996' Cy Eller cy.eller@conocophillips.com RWO/CTD Engineer Subsequent Form Required: Suspension Expiration Date: Authorized Name and Digital Signature with Date: PRESENT WELL CONDITION SUMMARY Length Size Kuparuk River Field TVD Perforation Depth TVD (ft): MD 9-5/8" 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. Proposed Pools: 10113' Burst 1754' 103' AOGCC USE ONLY Tubing Grade: L-80 Packers and SSSV MD (ft) and TVD (ft): 13. Well Class after proposed work: Tubing MD (ft): 9000' 8982'MD/3664'TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025636, ADL0025637, ADL0025639 224-092 P.O. Box 100360, Anchorage, AK 99510 50-029-23795-00-00 ConocoPhillips Alaska, Inc Will perfs require a spacing exception due to property boundaries? 120'120' 1793' 3903' 20" 13-3/8" 80' 1763' 8/29/2025 9253'271' Tubing Size: 4-1/2" 3752' BAKER SLZXP SSSV: None Perforation Depth MD (ft): 3996'8429'3541'8429' KRU 1H-107 None 10075' 3-1/2" None m n P 2 6 5 6 t g N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:06 pm, Aug 25, 2025 325-514 A.Dewhurst 26AUG25 DSR-8/26/25 10-404 AOGCC witnessed BOP and Annular test to 2500 psi. X JJL 8/25/25JLC 8/27/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.27 09:15:12 -08'00'08/27/25 RBDMS JSB 082725 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 25, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KRU 1H-107 (PTD# 224-092). Well 1H-107 was spudded in August of 2024 and completed in October of 2024 by Doyon 25 as a West Sak B and C Sand dual lateral producer. The well was initially brought online as a gas lift producer, then converted to an ESP producer when the retrievable AccessESP assembly was installed in March of 2025. The well recently experienced an ESP cable failure and will be converted to gas lift until the workover rig can be moved to the well. We are requesting approval to proceed with a rig workover. We plan to pull the 4-1/2” ESP completion, perform a cleanout run as needed, then install a new 4-1/2” ESP completion. If you have any questions or require any further information, please contact me at 907-265-6049. Cy Eller Rig Workover Engineer CPAI Drilling and Wells 1H-107 West Sak Producer Pull and Replace ESP Completion PTD: 224-092 Pre-Rig Work Remaining 1. T-POT and PPPOT. IC-POT and PPPOT. 2. MIT-IA to 2,500 psi for 30 minutes. 3. Shift sliding sleeve or pull valve from GLM for circulation point. 4. Prepare well for rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 1H-107. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve 4-1/2” Access ESP Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing string and jewelry from sealbore at 9,004’ RKB. Casing Cleanout/Drift Run 6. MU cleanout/drift BHA, PU drillpipe and perform casing cleanout to sealbore as needed, based on tubing condition. Install New 4-1/2” Access ESP Completion 7. MU new 4-1/2” completion with seal assembly, chemical injection mandrel, AccessESP assembly, downhole gauge, and gas lift mandrels. RIH to sealbore. 8. Once on depth, sting into sealbore, calculate space out. Circulate corrosion inhibited fluid. 9. Land tubing in sealbore, land tubing hanger, RILDS. 10. Pressure test tubing to 3,000 psi for 30 minutes. 11. Pressure test IA to 2,500 psi for 30 minutes. ND BOP, NU Tree 12. Confirm pressure tests, then shear out SOV. 13. Install BPV and test. ND BOPE. NU tree and PT packoffs. 14. Pull BPV and freeze protect well. 15. RDMO. Post-Rig Work 1. Pull SOV. Install new DMY. 2. Install retrievable AccessESP assembly. General Well Information: Estimated Start Date:8/29/2025 Page 1 of 2 1H-107 West Sak Producer Pull and Replace ESP Completion PTD: 224-092 Page 2 of 2 Current Operations: Attempting to bring well online with gas lift Well Type: Producer Wellhead Type: StreamFlo DMLX. 13-3/8” 5M tubing head top flange. Scope of Work: Perform a like-kind pull and replace of the 4-1/2” AccessESP. Pull the existing 4- 1/2” AccessESP completion from seals, perform a cleanout run as needed based on tubing condition, then install a new 4-1/2” AccessESP completion. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams FFollowing subject to change with Pre-Rig Work: MIT Results: MIT-IA: Passed when installed (2,500 psi, 10/4/2024) MIT-OA: Open Shoe Tubing POT & PPPOT: Passed when installed (10/5/2024) IC POT & PPPOT: Passed when installed (8/29/2024) Static BHP: 1,344 psi / 3,764’ TVD measured on 10/28/2024 MPSP: 986 psi using 0.1 psi/ft gradient Personnel: Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com) Production Engineer: Natalie Dye P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, ConocoPhillips Well Integrity Field Supervisor RBDMS JSB 081425 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.11 16:34:01-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green ConocoPhillips Alaska Inc.Well Name API # PTD #Initial top of cementVol. of Portland Type I cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant datein gal in gal1C-17 50-029-22872-00-00 198-224 N/AN/A post SC Repair8" N/A 0.85 8/7/20251C-150 50-029-23496-00-00 213-120 N/AN/A Rig cemented to surface4" N/A 3 8/7/20251C-152 50-029-23548-00-00 215-114 50" 34.4 9" 7/31/2025 2.13 8/7/20251C-153 50-029-23549-00-00 215-116 N/AN/A Rig cemented to surface9" N/A 1.73 8/7/20251C-154 50-029-23559-00-00 215-166 70" 51.8 10" 7/31/2025 3.4 8/7/20251C-155 50-029-23561-00-00 215-180 64" 35.8 8" 7/31/2025 1.7 8/7/20251C-15650-029-23750-00-00 223-023 25" 12.00 10" 7/31/2025 5.1 8/7/20251C-157 50-029-23754-00-00 223-038 57" 30.28 9" 7/31/2025 2.2 8/7/20251C-15850-029-23761-00-00 223-056 3"N/A Rig cemented to surface10" 7/31/2025 4.25 8/7/20251C-501 50-029-23757-00-00 223-045 139" 11.40 8" 7/31/2025 3.8 8/7/20251H-107 50-029-23795-00-00 224-092 34" 14.80 10" 7/31/2025 5.25 8/7/20251H-11250-029-23787-01-00 224-032 47" 33.19 7" 7/31/2025 4.25 8/7/20251H-12050-029-23794-01-00 224-081 30" 13.70 8" 7/31/2025 4 8/7/20253H-3550-103-20805-00-00 219-064 45" 32.20 7" 8/1/2025 3.6 8/8/20253H-3650-103-20838-00-00 222-014 60" 44.20 8" 8/1/2025 3.4 8/8/20253H-3750-103-20822-00-00 219-194 35" 23.00 8" 8/1/2025 3.4 8/8/2025Date 08/09/251C, 1H, and 3H PadsKuparuk FieldReport of Sundry Operations (10-404)Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off1H-10750-029-23795-00-00224-09234"14.8010"7/31/20255.258/7/2025 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory 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 12629'feet 8429' feet true vertical 3996' feet None feet Effective Depth measured 8429'feet 8982'feet true vertical 3541' feet 3665' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-3/4" 4-1/2" L-80 8539' MD 9000' MD 3556' TVD 3670' TVD Packers and SSSV (type, measured and true vertical depth)8982' MD N/A 3664' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 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: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 1200 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker SLZXP SSSV: None Natalie Dye Natalie.B.Dye@conocophillips.com (907) 265-1027Senior Production Engineer None None Main Bore Dual String Module 271' Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 6300 Gas-Mcf MD 1300 Size 120' 10 10901580 4700 37010 375 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 224-092 50-029-23795-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025636, ADL0025637, ADL0025639 Kuparuk River Oil Field/ West Sak Oil Pool KRU 1H-107 Intermediate 20" 13-3/8" 80' measured TVD 9-5/8" Plugs Junk measured Length measured true vertical Packer Burst Collapse Seal Bore Diverter Main Bore Screen Liner 10075' 103' 6956' Casing 3903' 3778' 4-1/2" 10113' 9333' 16255' 3996' 1754' 120'Conductor Surface 3-1/2" 9253' 3752' 1793' 1763' 9.63" Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:48 am, Apr 23, 2025 Natasha Dye Digitally signed by Natasha Dye Date: 2025.04.23 06:41:46 -08'00' JJL 5/8/25 RBDMS JSB 042525 DSR-4/25/25 DTTMSTART JOBTYP SUMMARYOPS 3/21/2025 OPTIMIZE WELL SET 4.5'' SLIP STOP CATCHER BELOW ST # 2 6968' RKB, PULLED 1'' OV w/ BK ST # 2, INSTALLED 1'' 2400# SOV w/ BK LATCH, PULLED 1'' GLV w/ BK LATCH ST #1, INSTALLED 1'' DMY VLV w/ BK LATCH, ATTEMPT TEST BELOW ST # 2, UNABLE TO GET HF DOWN, GOOD 500 PSI DP TEST BELOW ST#1, PULL SS CATCHER 6968' RKB - READY FOR COIL ESP INSTALL 3/22/2025 OPTIMIZE WELL MIRU CTU 14, PULL ISO SLEEVE AT 8,530' RKB, SHIFT CAMCO NEXA CMU SLEEVE OPEN @ 8873'. JOB IN PROGRESS. 3/22/2025 OPTIMIZE WELL DEPLOYED 4.5'' x 57' BAKER ESP MOTOR... 3/23/2025 OPTIMIZE WELL SHIFT CMD GAS VENTING SLEEVE OPEN @ 8465' CTMD, STANDBY FOR SLICKLINE, 8495' CTMD TAGGED NO GO TO SET MOTOR, UNABLE TO SET MOTOR, PULLED OOH DID NOT HAVE MOTOR, SWAP OUT GS AND ADD CENTRALIZER, RBIH, TRY THE SETTING SEQUENCE AGAIN, GOT MOTOR CONNECTED. JOB IN PROGRESS. 3/23/2025 OPTIMIZE WELL DEPLOYED BAKER 4.5'' x 57' ESP MOTOR FOR COIL TUBING 3/24/2025 OPTIMIZE WELL BAKER/ACCESS RECOMMEND PULLING MOTOR AS THEY HAVE NO GAUGE READINGS (ELECT. CONNECTION GOOD 10.5 OHMS), POOH AND MOTOR NOT RECOVERED, ADD CENTRALIZER, RBIH TO TAG @ 8457' CTMD, 1 JARLICK DOWN (7K OVERPULL), POOH AND MOTOR NOT RECOVERED AGAIN, RIH WITH VENTURI, TAG MOTOR @ 8453' CTMD, VENTURI FOR 15 MINUTES, TOOLS CAME BACK EMPTY AND CLEAN, CHANGE PACKOFFS AND TRIM 50' OF PIPE, TAG MOTOR AT 8543' CTMD 2 JARLICKS DOWN, AT SURFACE SWAB WILL NOT CLOSE (FISH ON), RBIH TO DROP OFF MOTOR AT 3000' CTMD, STANDBY FOR SLICKLINE, JOB IN PROGRESS. 3/24/2025 OPTIMIZE WELL PULLED BAKER 4.5'' x 57' ESP MOTOR FOR COIL TUBING 3/25/2025 OPTIMIZE WELL DEPLOYED 4.5'' X 57' BAKER ESP MOTOR FOR COIL TUBING, DEPLOYED SUMMIT PUMP FOR COIL. 3/25/2025 OPTIMIZE WELL PUSH MOTOR TO NO GO @ 8567' RKB, PU GET 5KOVERPULL AT 8554' B PROFILE, PU TO LOCATER @ 8463', GOT A 6K OVERPULL, BAKER TESTED CONNECTION SHOWING OPEN CIRCUIT. RIH AND SET MOTOR. GOT CONNECTION SHOWING 10.5 OHMS. GOOD TEST. SLICKLINE DEPLOYED MOTOR AND DROPPED OFF ~2900' SLMD. STAB BACK ON WITH COIL, PICK UP PUMP AND RIH TO MULTIPLE TAGS AT 7,208' WORK PAST TO HARD TAG AT 7,457'. POOH, NO PUMP, INSPECT BHA, RBIH, FIND PUMP ~122' DEEPER AT 7,579' CTMD. PUSH PUMP TO 8,415 CTMD. POOH, NO PUMP. INSPECT BHA, ADD JARS AND RBIH TO MIDNIGHT DEPTH OF 4,026' CTMD. JOB IN PROGRESS. 3/26/2025 OPTIMIZE WELL CONTINUE TO RIH FROM 4,026' CTMD. TAG SUMMIT PUMP AT 8,414' CTMD, 8435' RKB. SET PUMP AND PUMP OFF IT, POOH. SET RBP WITH STANDING VALVE, PT TUBING TO 1300 PSI. GOOD TEST, PULL CALIPER LOG FROM 8400' TO SURFACE - GOOD DATA. START WEEKLY BOP TEST. JOB IN PROGRESS. 3/26/2025 OPTIMIZE WELL STAND BY FOR COIL TO SET SUMMIT ESP PUMP / SET & TEST 4.5'' PACKOFF 3/27/2025 OPTIMIZE WELL COMPLETE BOP TEST. TRIM 50' OF PIPE NEW STRING LENGTH 22,000'. RD CTU #14. JOB COMPLETE. 1H-107 Convert Gas Lift to ESP Summary of Operations Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull ACP ISO, Shift Sleeves open, Set ESP 1H-107 3/26/2025 appleha Notes: General & Safety Annotation End Date Last Mod By Note: Chrome tubing below 8,939'famaj Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread Conductor2019.12 39.7 120.0 120.0 78.67 B Surface 13 3/8 12.42 39.5 1,793.0 1,762.9 68.00 L-80 H563 Seal Bore Diverter 9.63 7.76 9,230.1 9,333.4 3,777.6 29.70 13Cr-80 N/A Intermediate 9 5/8 8.84 38.2 10,112.7 3,902.8 40.00 L-80 Hydril 563 Main bore Screen liner 4 1/2 3.96 9,298.7 16,254.5 3,996.1 12.60 13CR-80 JFEBear Main Bore Dual string module 3 1/2 2.99 8,982.1 9,253.3 3,752.2 9.20 13Cr-80 VamTop Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth… 9,000.3 Set Depth… 3,670.4 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.9 36.9 0.00 Hanger 13.475 Streamflo hanger 4" H BPV, 6.25" acme lift threads - S/N StreamF lo DMLX 3.900 2,840.02,582.9 54.09 Mandrel 4.500 4-1/2" x 1" KBMG-1 GLM S/N 24190-09 SLB 4.5" x 1" KBMG 3.865 6,923.1 3,339.2 82.15 Mandrel 4.500 4-1/2" x 1" KBMG-1 GLM S/N 24190-05 SLB 4.5" x 1" KBMG 3.865 8,361.33,532.4 82.40Gauge / Pump Sensor 6.077 HES Opsis Gauge mandrel w/ Downhole gauge, 4-1/2" H563, L80 HES3.919 8,465.5 3,546.2 82.42 Sliding Sleeve 5.500 5-1/2" GV CMD Sliding sleeve 4 1/2" Vamtop Box x 5 1/2", 23#, Vam FJL Box ************ OPENED 3/23/25*************** Access ESP Sliding Sleeve 3.910 8,471.8 3,547.1 82.43 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,476.6 3,547.7 82.43 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,478.3 3,547.9 82.43 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,483.1 3,548.5 82.43 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,484.9 3,548.8 82.44 Motor Shroud 5.500 Motor Shroud, 5 1/2" Vam FJL Box x Pin Access ESP 3.894 8,489.7 3,549.4 82.44 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 4.548 8,491.4 3,549.6 82.44 Motor Shroud 5.500 Motor Shroud, 5 1/2" Vam FJL Box x Pin Access ESP 4.548 8,496.3 3,550.3 82.44 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,498.0 3,550.5 82.44 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,502.9 3,551.1 82.45 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 8,504.6 3,551.4 82.45 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,509.4 3,552.0 82.45 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,511.2 3,552.2 82.45 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,515.9 3,552.9 82.46 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,517.7 3,553.1 82.46 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,522.5 3,553.7 82.46 Motor Centralizer 5.500 Motor Cenralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.894 8,524.3 3,554.0 82.43 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 8,530.6 3,554.8 82.25 Annular Connection Port 5.950 Ann Connection Port, 5", 18# Vam FJL Box x 4 1/2" 12.6# Vamtop Box Access ESP 3.860 8,554.2 3,558.1 81.60 Profile Sub 4.500 B-Profile, 4 1/2", 12.6#, L-80 Vamtop Box x Box Access ESP 3.913 8,567.7 3,560.1 81.22 No-go nipple 5.000 No-Go, 4 1/2" 12.6# Vamtop Box x 4 1/2" Hyd 563 Box 3.805 8,873.3 3,630.1 72.37 Sliding Sleeve 5.490 CMU Sliding sleeve, 3.813" X Profile, 4-1/2", 12.6#, L80, H563 ******OPENED 3/22/25************ Camco NEXA CMU 3.813 8,939.1 3,650.7 71.39 Mandrel 5.600 HES Chemical injection mandrel, 4- 1/2" 12.6#, L80, H563 HES 4.330 8,999.5 3,670.1 71.11 Locator 5.190 Baker Locater 13Cr-80 3.880 9,000.3 3,670.4 71.10 Spacer tubes 13Cr-80 (10.68) 5.190 9,000.33,670.4 71.10 Baker Seal assembly 5.190 Baker 192-47 Seal assemblyw/ 3' of seals (3.18) 9,000.3 3,670.4 71.10 Mule Shoe Guide 5.190 Halliburton Self Aligning mule shoe guide (3.99) MULTIPLE LATERALS, 1H-107, 4/21/2025 1:01:50 PM Vertical schematic (actual) Main bore Screen liner; 9,298.7- 16,254.5 Intermediate; 38.2-10,112.7 Seal Bore Diverter; 9,230.1- 9,333.4 Main Bore Dual string module; 8,982.1-9,253.3 L1 Screen Liner; 9,225.5- 16,125.6 L1 Dual String module; 8,982.1- 9,267.1 Locator; 8,999.5 XO Threads; 8,993.3 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 Motor guide; 8,538.7 Plugarm assembly; 8,526.7 ESP Sensor; 8,523.1 ESP Motor; 8,498.6 ESP MOTOR; 8,482.0 Seal; 8,490.5 Seal; 8,482.3 Lower-mating Unit; 8,481.0 Upper-mating Unit; 8,480.6 Intake - ESP; 8,477.1 Intake - ESP; 8,473.5 Sliding Sleeve; 8,465.5 Pump - ESP; 8,451.6 ESP; 8,435.0 Pump - ESP; 8,429.8 RBP; 8,428.9 Discharge Head; 8,429.3 Polishbore receptacle; 8,428.1 Stinger Seal; 8,427.8 Standing Valve; 8,426.8 X-over; 8,426.3 Tubing Packoff; 8,422.0 Tubing Stop; 8,420.8 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 6,923.1 Mandrel; 2,840.0 Surface; 39.5-1,793.0 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Hanger; 36.9 KUP PROD KB-Grd (ft) 39.50 RR Date 10/5/2024 Other Elev… 1H-107 ... TD Act Btm (ftKB) 16,269.0 Well Attributes Field Name Wellbore API/UWI 500292379500 Wellbore Status PROD Max Angle & MD Incl (°) 92.92 MD (ftKB) 15,635.59 WELLNAME WELLBORE Annotation End DateH2S (ppm)DateComment Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 8,420.8 Set Depth… 8,539.1 Set Depth… 3,556.0 String Max No… 3 3/4 Tubing Description Tubing - Pump Insert Wt (lb/ft) 530.00 Grade Top Connection ID (in) Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,426.33,541.082.40 X-over 3.720 X-over Crossover D&D 8,426.8 3,541.1 82.40 Standing Valve 3.720 Standing Valve, 2 7/8" NU PxP D&D 10850-1 2.000 8,427.8 3,541.2 82.40 Stinger Seal 3.720 Stinger w/ Chevron Packing D&D 10851-1 2.250 8,428.1 3,541.3 82.40 Polishbore receptacle 3.720 RECEPTACLE, 4.5IN 12.6-12.75 HI- FLOW STEEL W/2.375IN EUE PIN CONNECTION D&D10825 8,429.3 3,541.4 82.40 Discharge Head 3.720 DISCHARGE, BOLT ON, 2 3/8IN, 8RD, 400X, 416 SS, 3.80IN SPECIAL Summit ESP 400X. 416 SS 8,429.8 3,541.5 82.40 Pump - ESP 3.800 PMP,400,SF5800,67S,INC,15,2:1,3. 8,TLK,D7 Summit ESP SF5800 AR, NO15, 67S 8,451.6 3,544.4 82.41 Pump - ESP 3.800 PMP,400,SF5800,67S,INC,15,2:1,3. 8,TLK,D7 Summit ESP SF5800 AR, NO15, 67S 8,473.5 3,547.3 82.43 Intake - ESP 3.800 GAS SEPARATOR, HIGH FLOW, 2 STAGE, UPPER TANDEM, 400X, VORTEX 3, STAINLESS STEEL, INCONEL SHAFT, DURAHARD 7 & DURAHARD 15, 3.80 OD Summit ESP Gas Separat or, 400 HighFlo w 8,477.1 3,547.7 82.43 Intake - ESP 3.800 GAS SEPARATOR, HIGH FLOW, 2 STAGE, SINGLE/LOWER TANDEM, 400X, VORTEX 3, STAINLESS STEEL, INCONEL SHAFT, DURAHARD 7 & DURAHARD 15, 3 Summit ESP Gas Separat or, 400 HighFlo w 8,480.6 3,548.2 82.43 Upper-mating Unit 3.750 Upper Mating Unit AccessE SP 08301-1 8,481.0 3,548.3 82.43 Lower-mating Unit 3.750 Lower Mating Unit AccessE SP 08374-1 8,482.3 3,548.4 82.43 Seal 3.380 SEAL, 338 SERIES, BSBSL, UPPER TANDEM, PREMIUM SEALS, SPECIAL, INCONEL SHAFT Summit ESP 338, BSBSL 8,490.5 3,549.5 82.44 Seal 3.380 SEAL, 338 SERIES, BSBSL, PREMIUM SEALS, SPECIAL, INCONEL SHAFT Summit ESP 338, BSBSL 8,498.6 3,550.6 82.44 ESP Motor 3.750 Motor, 375 Series, Competitor Equipment, 400HP/AccessESP motor AccessE SP A375, 400HP 8,523.13,553.882.46 ESP Sensor 3.750 AccessE SP/Zenit h 67065-5 8,526.7 3,554.3 82.36 Plugarm assembly 3.750 AccessE SP 07851-3 8,538.7 3,555.9 82.03 Motor guide 3.750 AccessE SP 06505-2 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,428.9 3,541.4 82.40 RBP 4.5" P2P PACKER, HANGOFF XO, STANDING VALVE WITH CHECK BALL AND SEAL STINGER, STUNG INTO TOP OF PUMP. CPP4 5036 3/26/2025 2.000 8,435.0 3,542.2 82.40 ESP 53.20' SUMMIT DUAL STAGE PUMP, 380, 67 STG, SF5800, T52. 3/25/2025 8,482.0 3,548.4 82.43 ESP MOTOR 57' ACCESS ESP 250 HP 4 POLE PPM MOTOR. 3/25/20250.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 2,840.0 2,582.9 54.09 1 GAS LIFT DMY BK 1 3/21/2025SLB KBMG 6,923.1 3,339.2 82.15 2 GAS LIFT SOVBK 1 3/21/2025 2400#SLB KBMG Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,982.1 3,664.5 71.18 PACKER 9.625 Baker SLZXP w/ HD 10' ext, 9- 5/8" x 7" 29# H563 pin down 13 Cr -80 TOL xxxx' Baker SLZXP 7.380 9,003.7 3,671.5 71.10 XO Threads 7.000 Crossover sub, 7" 26# H563 x 5- 1/2" 15.5# H563 pin 13Cr-80 4.890 9,005.1 3,672.0 71.10 SBR 5.500 Baker 190-47 Seal bore, 5-1/2" 15.5# H563 B x P, 13Cr-80 Baker SBE 4.750 9,033.9 3,681.3 71.07 XO Threads 7.000 Crossover sub, 5-1/2" H563 x 7" H563, 13Cr-80 4.950 9,035.63,681.8 71.07FLCV7.000 7" FLCV, 7" H563 BxP 13Cr-80 (Locked open by pressuring up, sheared @ 2250 PSI, on 10/13/24) Baker4.570 9,042.4 3,684.1 71.06 XO Threads 7.000 Crossover sub, 7" H563 x 5-1/2" H563, 13Cr-80 4.950 MULTIPLE LATERALS, 1H-107, 4/21/2025 1:01:54 PM Vertical schematic (actual) Main bore Screen liner; 9,298.7- 16,254.5 Intermediate; 38.2-10,112.7 Seal Bore Diverter; 9,230.1- 9,333.4 Main Bore Dual string module; 8,982.1-9,253.3 L1 Screen Liner; 9,225.5- 16,125.6 L1 Dual String module; 8,982.1- 9,267.1 Locator; 8,999.5 XO Threads; 8,993.3 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 Motor guide; 8,538.7 Plugarm assembly; 8,526.7 ESP Sensor; 8,523.1 ESP Motor; 8,498.6 ESP MOTOR; 8,482.0 Seal; 8,490.5 Seal; 8,482.3 Lower-mating Unit; 8,481.0 Upper-mating Unit; 8,480.6 Intake - ESP; 8,477.1 Intake - ESP; 8,473.5 Sliding Sleeve; 8,465.5 Pump - ESP; 8,451.6 ESP; 8,435.0 Pump - ESP; 8,429.8 RBP; 8,428.9 Discharge Head; 8,429.3 Polishbore receptacle; 8,428.1 Stinger Seal; 8,427.8 Standing Valve; 8,426.8 X-over; 8,426.3 Tubing Packoff; 8,422.0 Tubing Stop; 8,420.8 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 6,923.1 Mandrel; 2,840.0 Surface; 39.5-1,793.0 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Hanger; 36.9 KUP PROD 1H-107 ... WELLNAME WELLBORE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,053.0 3,687.5 71.05 XO Threads 5.500 Crossover sub, 5-1/2" H563 x 4- 1/2" H563, 13Cr-80 Baker 3.850 9,054.6 3,688.0 71.05 XO Threads 4.500 Crossover sub, 4-1/2" H563 x 4- 1/2" VamTop, 13Cr-80 3.850 9,074.3 3,694.4 71.03 Swivel 4.500 Telescoping swivel sub, 4-1/2" VamTop, 13Cr-80, 24" Stroke Baker 3.870 9,088.5 3,699.0 71.02 Selective Re- entry Tool 4.500 Selective re-entry tool (MB and L1), 4-1/2" VT Box x (2) 3-1/2" VT box down Baker SRT 3.740 9,122.0 3,709.9 71.09 Swivel 3.500 Swivel Sub (mainbore) 3-1/2" 9.2#, VamTop BxP, 13Cr-80 Baker2.960 9,138.7 3,715.3 71.13 Nipple - XN 3.500 2.813" XN, WITH A 2.75" NO-GO (mainbore), 3-1/2" 9.2# VamTop 13Cr-80 HES XN 2.750 9,183.0 3,729.6 71.22 XO Threads 3.500 Main bore XO 3-1/2" VT x 3.220" 7.9# SSDS-8 Pin 2.700 9,230.1 3,744.8 71.27 Window 9.630 Baker Seal Bore diverter, L5. Pos #1, 4-1/2" H563 pin (6.75' above TOW) 13Cr BakerRAM L5 SBD L1 7.760 9,257.83,753.6 71.30 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" H563 x JFE Bear 13Cr-80 3.900 9,286.1 3,762.7 71.38 Nipple 4.500 No Go sub w/ 2.6" Tapered ID, 4- 1/2" JFE Bear 13Cr-80 BakerNo Go 2.600 9,287.4 3,763.1 71.39 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" JFE Bear x H563, 13Cr-80 3.910 9,307.13,769.4 71.54 Anchor 7.300 RAM ML Production Anchor (120k snap) 4-1/2" 12.6# 13Cr-80 above collet BakerRAM XL 3.910 9,311.7 3,770.8 71.57 Anchor 6.250 RAM ML Production Anchor (120k snap) 4-1/2" 12.6# 13Cr-80 below collet BakerRAM XL 3.910 9,314.0 3,771.6 71.59 XO Threads 4.500 Crossover Tubing pup joint, 4-1/2" H563 x STL pin, 4-1/2" 12.6#, 13Cr-80 3.890 9,325.23,775.1 71.67XO Reducing 7.650 Baker 4.900 9,336.4 3,778.6 71.75 XO Enlarging 5.500 Baker 4.890 9,343.1 3,780.7 71.80 KOIV Isolation Tool 8.030 BakerKOIV 5.150 9,346.23,781.7 71.82 C-2 Knock Out Isolation Valve 7.000 C-2 Knock Out Isolation Valve Baker 6.120 9,348.6 3,782.4 71.84 XO Reducing 5.500 Baker 4.900 9,392.0 3,795.7 72.62 XO Reducing 4.500 3.958 10,311.4 3,906.4 90.85 Packer - Swell 6 4.500 TAM 3.958 10,450.93,904.191.10 Packer - Swell 54.500 TAM 3.958 13,052.3 3,941.2 87.25 Packer - Swell 4 4.500 TAM 3.958 14,224.4 3,986.8 88.39 Packer - Swell 3 4.500 TAM 3.958 14,721.3 4,012.0 87.34 Packer - Swell 2 4.500 TAM 3.958 15,456.6 4,014.1 91.18 Packer - Swell 1 4.500 TAM 3.958 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 39.7 1,793.0 39.7 1,762.9 Surface String Cement Pump 100 BBLS 10.9 PPG mud push, Pump 308 BBLS 11 PPG lead cement, see mud push at surface 280 BBLS away into lead, pump 71 BBLS 15.8 PPG tail cement, pump 20 BBLS H2O, chase with 232 BBLS 9.6 PPG spud mud, see 11.0 PPG lead cement at surface at 180 BBLS into Displacement, bump plugs, check floats, floats hold. 8/20/2024 3,981.0 10,112.0 2,942.8 3,902.8 Intermediate String 1 Cement 8/29/2024 MULTIPLE LATERALS, 1H-107, 4/21/2025 1:01:59 PM Vertical schematic (actual) Main bore Screen liner; 9,298.7- 16,254.5 Intermediate; 38.2-10,112.7 Seal Bore Diverter; 9,230.1- 9,333.4 Main Bore Dual string module; 8,982.1-9,253.3 L1 Screen Liner; 9,225.5- 16,125.6 L1 Dual String module; 8,982.1- 9,267.1 Locator; 8,999.5 XO Threads; 8,993.3 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 Motor guide; 8,538.7 Plugarm assembly; 8,526.7 ESP Sensor; 8,523.1 ESP Motor; 8,498.6 ESP MOTOR; 8,482.0 Seal; 8,490.5 Seal; 8,482.3 Lower-mating Unit; 8,481.0 Upper-mating Unit; 8,480.6 Intake - ESP; 8,477.1 Intake - ESP; 8,473.5 Sliding Sleeve; 8,465.5 Pump - ESP; 8,451.6 ESP; 8,435.0 Pump - ESP; 8,429.8 RBP; 8,428.9 Discharge Head; 8,429.3 Polishbore receptacle; 8,428.1 Stinger Seal; 8,427.8 Standing Valve; 8,426.8 X-over; 8,426.3 Tubing Packoff; 8,422.0 Tubing Stop; 8,420.8 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 6,923.1 Mandrel; 2,840.0 Surface; 39.5-1,793.0 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Hanger; 36.9 KUP PROD 1H-107 ... WELLNAME WELLBORE Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread L1 Screen Liner 4 1/2 3.96 9,225.5 16,125.6 3,926.4 12.60 13Cr-80 JFE Bear L1 Dual String module 3 1/2 2.99 8,982.1 9,267.1 3,756.2 9.20 13Cr-80 VamTop Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,003.63,671.5 71.10 XO Threads 7.000 Crossover sub, 7" 26# H563 x 5- 1/2" 15.5# H563 pin 13Cr-80 4.890 9,005.1 3,671.9 71.10 SBR 5.500 Baker 190-47 Seal bore, 5-1/2" 15.5# H563 B x P, 13Cr-80 Baker SBE 4.750 9,033.9 3,681.3 71.07 XO Threads 7.000 Crossover sub, 5-1/2" H563 x 7" H563, 13Cr-80 4.950 9,035.63,681.8 71.07FLCV7.000 7" FLCV, 7" H563 BxP 13Cr-80 Baker 4.570 9,042.4 3,684.0 71.06 XO Threads 7.000 Crossover sub, 7" H563 x 5-1/2" H563, 13Cr-80 4.950 9,052.9 3,687.5 71.05 XO Threads 5.500 Crossover sub, 5-1/2" H563 x 4- 1/2" H563, 13Cr-80 Baker 3.850 9,054.6 3,688.0 71.05 XO Threads 4.500 Crossover sub, 4-1/2" H563 x 4- 1/2" VamTop, 13Cr-80 3.850 9,074.3 3,694.4 71.03 Swivel 4.500 Telescoping swivel sub, 4-1/2" VamTop, 13Cr-80, 24" Stroke Baker 3.870 9,088.4 3,699.0 71.02 Selective Re- entry Tool 4.500 Selective re-entry tool (MB and L1), 4-1/2" VT Box x (2) 3-1/2" VT box down Baker SRT 3.740 9,126.3 3,711.3 71.10 Swivel 3.500 Swivel Sub (mainbore) 3-1/2" 9.2#, VamTop BxP, 13Cr-80 Baker 2.960 9,189.0 3,731.5 71.22 Nipple - XN 3.500 2.813" XN WITH A 2.75" NO-GO (L1), 3-1/2" 9.2# VamTop 13Cr-80 HES XN 2.750 9,190.3 3,732.0 71.22 XO Threads 3.500 L1 XO 3-1/2" VT x 3.220" 7.9# SSDS-8 Pin 2.700 9,271.9 3,757.6 73.15 XO Reducing 5.500 Crossover Sub, 5-1/2" 15.5# H563 x 4-1/2", 12.6# JFE Bear, 13 Cr- 80 3.930 10,384.7 3,833.9 90.94 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #6 TAM FREECAP 5' 3.958 10,760.6 3,825.1 90.42 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #5 TAM FREECAP 5' 3.958 12,330.7 3,850.1 87.93 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #4 TAM FREECAP 5' 3.958 14,177.4 3,913.9 87.31 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #3 TAM FREECAP 5' 3.958 14,671.5 3,947.5 87.32 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #2 TAM FREECAP 5' 3.958 15,365.1 3,942.1 91.44 Packer - Swell 4.500 PACKER,SWELL 4-1/2" x 6.38", TAM FREECAP I, 5' element. #1 TAM FREECAP 5' 3.958 16,072.63,927.7 91.45 Drillable packoff bushing 4.500 Drillable Packoff Bushing, 4-1/2", 12.6#, 13Cr-80, JFE Bear BakerDPOB 3.958 MULTIPLE LATERALS, 1H-107L1, 4/21/2025 1:02:03 PM Vertical schematic (actual) L1 Screen Liner; 9,225.5- 16,125.6 L1 Dual String module; 8,982.1- 9,267.1 Main Bore Dual string module; 8,982.1-9,253.3 Seal Bore Diverter; 9,230.1- 9,333.4 Intermediate; 38.2-10,112.7 Locator; 8,999.5 XO Threads; 8,993.3 Mandrel; 8,939.1 Sliding Sleeve; 8,873.3 Motor guide; 8,538.7 Plugarm assembly; 8,526.7 ESP Sensor; 8,523.1 ESP Motor; 8,498.6 ESP MOTOR; 8,482.0 Seal; 8,490.5 Seal; 8,482.3 Lower-mating Unit; 8,481.0 Upper-mating Unit; 8,480.6 Intake - ESP; 8,477.1 Intake - ESP; 8,473.5 Sliding Sleeve; 8,465.5 Pump - ESP; 8,451.6 ESP; 8,435.0 Pump - ESP; 8,429.8 RBP; 8,428.9 Discharge Head; 8,429.3 Polishbore receptacle; 8,428.1 Stinger Seal; 8,427.8 Standing Valve; 8,426.8 X-over; 8,426.3 Tubing Packoff; 8,422.0 Tubing Stop; 8,420.8 Mandrel; 6,923.1 Intermediate String 1 Cement; 3,981.0 ftKB Mandrel; 2,840.0 Surface; 39.5-1,793.0 Surface String Cement; 39.7 ftKB Conductor; 39.7-120.0 Hanger; 36.9 KUP PROD KB-Grd (ft) 39.50 RR Date 10/5/2024 Other Elev… 1H-107L1 ... TD Act Btm (ftKB) 16,163.0 Well Attributes Field Name Wellbore API/UWI 500292379560 Wellbore Status PROD Max Angle & MD Incl (°) 92.96 MD (ftKB) 10,145.72 WELLNAME WELLBORE Annotation End DateH2S (ppm)DateComment C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-03-26_22216_KRU_1H-107_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22216 KRU 1H-107 50-029-23795-00 Caliper Survey w/ Log Data 26-Mar-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 224-092 T40246 4/1/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.01 08:38:14 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-01-10_23061_KRU_1H-107_LeakDetectionSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23061 KRU 1H-107 50-029-23795-00 Leak Detection Survey 10-Jan-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM 224-092 T39954 1/14/2025 1 Gluyas, Gavin R (OGC) From:Lau, Jack J (OGC) Sent:Monday, January 13, 2025 12:41 PM To:AOGCC Records (CED sponsored) Subject:FW: APPROVED : KRU 1H-107 (PTD 224-092) Request for temporary gas lift production with T x IA communication. Update 1/13/25 Attachments:1H-107 Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, January 13, 2025 12:39 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: APPROVED : KRU 1H-107 (PTD 224-092) Request for temporary gas lift production with T x IA communication. Update 1/13/25 Jack, KRU 1H-107 (PTD 224-092) T x IA communicaƟon has been repaired. The ACP iso sleeve at 8,530’ MD has been pulled and replaced by Coil. DHD followed up by performing a passing TIFL on 1/11/25. CPAI plans to return the well to “normal” status. AƩached is a wellbore schemaƟc for reference. Please let me know if you have any quesƟons with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, November 12, 2024 1:09 PM To: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com> Subject: [EXTERNAL]APPROVED : KRU 1H-107 (PTD 224-092) Request for temporary gas lift production with T x IA communication CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Shelby – Your request for a variance to operate KRU 1H-107 with TxIA comm on gas lifted production is granted until 1/14/25 given the following mitigations are in place. Install hardline to the flowline and IA of 1H-107, directly from the water injecƟon header The well will be monitored by both operaƟons and rig personnel 24/7 Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 OƯice (907) 227-2760 Cell From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Tuesday, November 12, 2024 9:39 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: FW: KRU 1H-107 (PTD 224-092) Request for temporary gas lift production with T x IA communication Jack, Please review current request for KRU 1H-107 and previous approval on KRU 3S-615. Note 1H-107 is a WSak well, low pressure, likely would not flow up the annulus. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Thursday, November 7, 2024 11:19 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com> Subject: KRU 1H-107 (PTD 224-092) Request for temporary gas lift production with T x IA communication Victoria, KRU 1H-107 (PTD 224-092)failed a TIFL on 11/5/24 and is on a 28 day Fix or Shut in clock which ends 12/3/24. Doyon 25 recently drilled and completed 1H-107 on 10/5/24 and obtained passing pressure tests of both the CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 tubing (1500 psi) and the IA (2000 psi) on 10/4/24 (see aƩached chart). 1H-107 was brought online on 10/29/24. Over the following days, the IA fluid level was monitored as the well unloaded the fluid from the IA with gas liŌ. The IA fluid level was observed at the sliding sleeve at 8466’ RKB, w hich is down past the orifice valve at 6923’ RKB. It is believed during post-rig operaƟons, coil inadvertently opened the sliding sleeve (see aƩached schemaƟc). Currently, Doyon 25 is drilling 1H-106 making 1H-107 inaccessible to intervenƟons. Doyon 25 is anƟcipated to move off 1H-106 on or around Dec 31st, 2024. Similar to the miƟgaƟon implemented on 3S-615 in March 2024 (see aƩached email). CPAI has devised a way to pump fluids to kill the well as needed and believes this should allow for a variance to temporarily produce the well unƟl the Doyon 25 rig is moved and intervenƟons can access 1H-107 as explained further below. A SBHP was collected on 10/28/24 before bringing the well online. The BHP was 1356 psi at 3210 Ō TVD, which equates to approximately 8.12 ppg. CPAI plans to install hardline to the flowline and IA of 1H-107, directly from the water injecƟon header. In the unlikely event that fluid injecƟon into 1H-107 becomes necessary as this would require the failure of mulƟple well barrier envelopes, CPAI operaƟons team would be ready to inject water down the tubing and transiƟon from liŌ gas injecƟon to water injecƟon down the IA, killing the well. CPAI also has the capability to dispatch pump trucks for pumping kill weight fluid as a conƟngency. AddiƟonally, with the rig in close proximity, the well will be monitored by both operaƟons and rig personnel 24/7. With this rig-up in place satisfying the ability to react to a well control event, CPAI requests a variance to allow for temporary gas lift production with TxIA communication until two weeks after Doyon 25 has moved off 1H- 106 (anticipated to occur on or around Dec 31st, 2024). Intervention operations will then begin on 1H-107 to diagnose and repair the TxIA communication. Please advise if this plan is acceptable. We are willing to come over and discuss the plan if it is needed. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 KUP PROD WELLNAME 11-1-107 WELLBORE 1H-107 ConocoPhillips Alaska, Inc. MULTIPLE LATERALS, 11-1-107, 11WO24 11:17:M AM Vertical Schematic (actual) Hanger, 38.2 Hanger, 39.5 1,789.4 Intermediate String 1 Sleeve; 8,465.5 EVE; 8,530.0- 3.880 ing Sleeve; 8,8732 ;KER - LINER; 12.1 :KER; 8,982.1 Threads; 8,993.3 Slot; 8,999.5 g; 9,005.0 g; 9.005.1 :V; 9.035.5 :V; 9,035.6 Threads; 9,052.9 Threads; 9,052.9 vet; 9,074.3 9,122.0 9,126.3 XN; 9,138.6 XN: 9,189.0 9,225.5 9,233A terribly. 91233 9 lembly; 9,233S 9.286.1 0,307.1 %311.7 Mule; 9.330.1 olWr, 10,021.5 hoe; 1ftIN 6 Well Attributes Max Angle &MD TO Held Name I WBIIbOM APIIDWI WBIIbOre Brain$ InCl l°I MD InKaI ACi Rot IXKBI 500292379500 PROD 92.92 1bd35.59 1Q269u Comment HRS 1ppml Date Annotabon En00ata K8.Orb Be RR Date Uther Elev.., 39.50 10/52024 I Annomlon Wellbore Eno Data tea Mod BY Ra;Reason: Install CALL), Lxk open FLCV With pressure 1H-107 101151202,1 iogerba Casing Strings Set Depot Set Depth Can ran OD fin) IO (in) Top Beat IaKBI nifinBWBI mr-en(IM) Grade Tap Thread COndu for 20 19.12 39.7 120.0 120.0 78.67 B Sadax 13318 12.42 39.5 1,793.0 1,762.9 68.00 L-80 H563 Seel Bore Divener 9.63 7.76 9,230.1 9.333.4 3,777.6 29.7013Cr-00 NIA Intermediate 9518 8.84 38.2 10,112.7 3,902.8 40.00 L-80 Hydril563 L1 Middle Completion 3112 2.99 8,982.1 9,267.1 3,756.6 9.2013Cr-80 V.oi Main Bore Middle 3112 299 8,982.1 9,253.3 3,752.2 9.2013Cr-80 Vari completion Tubing Strings: "String Max Nominal OD" Is the OD of the LONGEST segment In string Top (KKB) Birth Sat Depth... Being Max No.. Tobing Deactlptlan Wtg¢MI Grade Tap Conn.. ID 9n) ISO 0.0 9.000.3 3,670E 412 Tubing Production 12.W L:A Hyd563 3.96 Completion Details: excludes tubing, pup, space out, thread, IRKS... DD Top (Pi Top lnd Nominal Nominal Top IKKB) MKB) (°) Ibm Ons (in) Cam Make Modal ID (in) 38.9 36.9 0.00 Hanger 13.475 Sbeai1160 hanger 4"H Bp ,6.25" St.MF DMLX 3.900 acme lift threads - SIN Io 2,840.0 2,582.9 54.09 Mandrel 4,500 412' x V KBMG-1 GLM SIN SLB 4.F x 1" 3865 24190-09 KBMG 6,9nA 3,339.2 82.15 Mandrel 4.500 4-12' x 1" KBMG-1 GLM SIN SLB 4.F x 1" 3.865 24190-05 KBMG 8,361.3 3,5 A 82.40 Gauge I Pump 6.077 HES Opole Gauge mandrel wl HES 3.919 Sensor Downhole gauge, 4-12'11563, L80 8,465.5 3,646.2 82.42 Sliding Sleeve 5.600 6-12- GV Sliding sleeve 410 Access Sliding 3.910 Vamtop Box x 5 VT, 23k, Van FJL ESP Sleeve Box 3471.8 3,547.1 82.43 Motor Shroud 5.500 Motor Shroud, 511T 23# Van FJL Axess 4.548 Pin x Pin ESP 8,4766 3,547 7 8243 Motor 5500 Motor Cenralizer, 511723# Van Access 3Sea Centralizer FJL Box x BOx ESP 8,478.3 3,547.9 82.43 Motor Shroud 5.500 Motor Shroud, 511T 23k Vam FJL Access 4.548 Pin x Pin ESP 8,483.1 3,548.5 82.43 Motor 5.500 Motor Cenralizer, 511T 23# Van Access 3.893 Centrallzer FJL Box x Box ESP 8.,upta 3,548.8 82E4 Motor Shroud 5.500 Motor Shroud, 511T Van FJL Box x Axess 3.894 Pin ESP 8,489.7 3,549.4 82E4 Motor 5.500 Motor Cenmlizer, 5117 23# Vam Axess 4.548 Cenballrer FJL Box Box ESP 8,491E 3,549.6 8244 Motor Shroud 5503 Motor Shroud, 511T Van FJL Box x Access 4548 Pin ESP 3496.3 3.550.3 82.44 Motor 5.500 Motor Cenralizer, 511T 23# Van A not 3.894 Cenballmr FJL Box x Box ESP 8,496.0 3,550.5 82.44 Motor Shroud 5500 Motor Shroud, 511T 23# Van FJL Axess 4.548 Pin x Pin ESP 8,502S 3551.1 8245 Motor 5.500 Motor Cenrah.r, 511T 23# Van Axess 3.893 Centralizer FJL Box x Box ESP 8,504.E 3,551.4 82.45 Motor Shroud 5.500 Motor Shiaud, 511T 23k Vein FJL Axes 4.548 Pin x Pin ESP 8,509E 31552.0 82.45 Motor 5.500 Motor Cenialixer, 511T 2# Vain Access 3.894 Centrallrer FJL Box x Box ESP 8,511.213,�.O 82.45 Motor Shroud 5.500 Motor Shroud, 511T 23k Vain FJL A Oaa 4.548 Pin x Pin ESP 3515.9 82.46 Motor 5.500 Motor Cenmlizen 511T 23# Vam Axess 3.894 Ceotralimr FJL Box x Box ESP 8.5 77.7 82.4E Motor Shroud 5.500 Motor Shmud, 5112' 23k Vein FJL Axess 4.548 Pin x Pin ESP 8,522.5 82.4E Motor 5.5W Motor CenralizeD 511T 23# Vam Access 3.894 Centrallzer FJL Box Box ESP 8,524.3 82.43 Motor Shroud 5.500 Motor Shroud, 5112' 23k Vam FJL Axem 4.548 Pin x Pin ESP 8,530.E 82.25 Annular 5.950 Ann Connection Pon, 6'. 18# Vam Axes 3.850 Connection FJL Box x 4 VT'l 2.6k Vamtop Box ESP Pon 8,554.2 81.60 Pmfile Sub 4.SIX1 B-Pmfile, 412", 12.6#, L-90 Vamtop Axes 3.913 Boxx Box ESP 8,56)7 81.22 No-go nipple 5.000 No -Go, 412" 12.6a Vamtop Box x 4 3.805 11T Hyd 563 Box 8,873.3 3,630.1 72.37 Sliding Sleeve 5.490 CMU Sliding sleeve, 3.813"X Carron Sliding 3.813 Profile, 4-11T, 12.6#, 1_80, H563 Slevewl X-Prole PINi1381 NEXA27 642, SIN# 03 8,939.1 3,650.7 71.39 Mandrel 5.600 HES Chemical injection mandrel, 4- HES Chemica 4.330 11T 12.6#, LBO, H563 1 de Lion Mandrel, HES SAP# 1108136 8,M.51 3,670.11 71.11 Locator iSAW Baker Locater 13Cr-80 3.880 v.uuu.3 ofu.,i Ii.10 Spacern.a. 5.190 1311,80 I (10.68) r®� KUP PROD WELLNAME 1H-107 WELLBORE 7H-107 r®� KUP PROD WELLNAME 1H-107 WELLBORE 1H-107 From:Lau, Jack J (OGC) To:n1617@conocophillips.com Cc:Loepp, Victoria T (OGC); Hobbs, Greg S; Livingston, Erica J; NSK West Sak Prod Engr; Byrne, Jan Subject:APPROVED : KRU 1H-107 (PTD 224-092) Request for temporary gas lift production with T x IA communication Date:Tuesday, November 12, 2024 1:09:03 PM Shelby – Your request for a variance to operate KRU 1H-107 with TxIA comm on gas lifted production is granted until 1/14/25 given the following mitigations are in place. Install hardline to the flowline and IA of 1H-107, directly from the water injection header The well will be monitored by both operations and rig personnel 24/7 Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Tuesday, November 12, 2024 9:39 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: FW: KRU 1H-107 (PTD 224-092) Request for temporary gas lift production with T x IA communication Jack, Please review current request for KRU 1H-107 and previous approval on KRU 3S-615. Note 1H-107 is a WSak well, low pressure, likely would not flow up the annulus. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 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: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Thursday, November 7, 2024 11:19 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com>; Byrne, Jan <Jan.Byrne@conocophillips.com> Subject: KRU 1H-107 (PTD 224-092) Request for temporary gas lift production with T x IA communication Victoria, KRU 1H-107 (PTD 224-092)failed a TIFL on 11/5/24 and is on a 28 day Fix or Shut in clock which ends 12/3/24. Doyon 25 recently drilled and completed 1H-107 on 10/5/24 and obtained passing pressure tests of both the tubing (1500 psi) and the IA (2000 psi) on 10/4/24 (see attached chart). 1H-107 was brought online on 10/29/24. Over the following days, the IA fluid level was monitored as the well unloaded the fluid from the IA with gas lift. The IA fluid level was observed at the sliding sleeve at 8466’ RKB, which is down past the orifice valve at 6923’ RKB. It is believed during post-rig operations, coil inadvertently opened the sliding sleeve (see attached schematic). Currently, Doyon 25 is drilling 1H-106 making 1H-107 inaccessible to interventions. Doyon 25 is anticipated to move off 1H-106 on or around Dec 31st, 2024. Similar to the mitigation implemented on 3S-615 in March 2024 (see attached email). CPAI has devised a way to pump fluids to kill the well as needed and believes this should allow for a variance to temporarily produce the well until the Doyon 25 rig is moved and interventions can access 1H-107 as explained further below. A SBHP was collected on 10/28/24 before bringing the well online. The BHP was 1356 psi at 3210 ft TVD, which equates to approximately 8.12 ppg. CPAI plans to install hardline to the flowline and IA of 1H-107, directly from the water injection header. In the unlikely event that fluid injection into 1H-107 becomes necessary as this would require the failure of multiple well barrier envelopes, CPAI operations team would be ready to inject water down the tubing and transition from lift gas injection to water injection down the IA, killing the well. CPAI also has the capability to dispatch pump trucks for pumping kill weight fluid as a contingency. Additionally, with the rig in close proximity, the well will be monitored by both operations and rig personnel 24/7. With this rig-up in place satisfying the ability to react to a well control event, CPAI requests a variance to allow for temporary gas lift production with TxIA communication until two weeks after Doyon 25 has moved off 1H-106 (anticipated to occur on or around Dec 31st, 2024). Intervention operations will then begin on 1H-107 to diagnose and repair the TxIA communication. Please advise if this plan is acceptable. We are willing to come over and discuss the plan if it is needed. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Sep 30, 2024 AOGCC Attention: Meredith Guhl 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. KRU 1H-107/ KRU 1H-107L1 Kuparuk River API #: 50-029-23795-00-00/50-029-23795-60-00 Permit No: 224-092/224-093 Rig: Doyon 25 The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files. Thank you. Signature of receiver & date received: Please return transmittal letter to: Hampton, Jerissa Jerissa.Hampton@conocophillips.com Luis G Arismendi Luis.arismendi@bakerhughes.com 224-092 T39613 224-093 T39614 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.30 08:55:51 -08'00' 224-092 T39613 224 092 T39613 KRU 1H-107 50-029-23795-00-00 /224-092 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV U WSAK 1H-107 JBR 10/16/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 9 5/8" and 5" test joints used for testing. The audible and visual on the flow indicator failed to operate. There was a wiring issue that was fixed and it passed the retest. Test Results TEST DATA Rig Rep:E. Potter/C. BaliOperator:ConocoPhillips Alaska, Inc.Operator Rep:J. Benedict/L. Shirley Rig Owner/Rig No.:Doyon 25 PTD#:2240920 DATE:8/21/2024 Type Operation:DRILL Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopGDC240820071822 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 7 MASP: 1513 Sundry No: 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 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 9 5/8" Solid P #2 Rams 1 Blind/Shear P #3 Rams 1 2 7/8"x5" VB P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 2 3 1/8" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1900 200 PSI Attained P13 Full Pressure Attained P72 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@1850 ACC Misc NA P PTrip Tank P PPit Level Indicators FP FPFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P23 #1 Rams P7 #2 Rams P5 #3 Rams P6 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9999 9 9 9 7HVWFKDUWVDWWDFKHG audible and visual on the flow indicator failed to operate FP FP %23(7HVW'R\RQ .58+ 37' $2*&&,QVSERS*'& #01&5FTU%PZPO ,36) 15% "0($$*OTQCPQ(%$ 1H-107 8/21/2024 Tested to 250PSI/5MIN, 5000PSI/5MIN. ANN. T/ 3500PSI. 9 5/8” Test Jt. CHART #1 1. Annular Preventer 2. UPR’s (9 5/8” SBR’s) UIBOP, 4” Kill Line Valve. CMV: 1, 13, 14, 15 3. LIBOP HCR KILL CMV: 2,10,12 4. 5” Dart Valve, MAN KILL. CMV: 6,9,11 5. 5” FOSV #1, CMV: 5,7,8 6. 5” FOSV #2. CMV: 3 7. CMV: 4 8. HCR CHOKE 9. MAN CHOKE CHART #2 10. Manually Op & Super Choke (10A = SUPER Choke – 10B = MANUAL Choke) 11. BLINDS 5” Test Jt. 12. Annular Preventer 13. LPR’s (2 7/8 X 5 VRB’s) %23(7HVW'R\RQ .58+ 37' $2*&&,QVSERS*'& 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 Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H-107 Conoco Phillips Alaska, Inc. Permit to Drill Number: 224-092 Surface Location: 11 FNL, 766 FEL, S33 T12N R10E, UM Bottomhole Location: 150 FSL, 2137 FEL, S14 T12N R10E, UM Dear Mr. Brillon: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. 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, -HVVLH/&KPLHORZVNL &RPPLVVLRQHU DATED this 31st day of July. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.31 14:11:31 -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: 16,249 TVD: 3999 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): 93 15. Distance to Nearest Well Open Surface: x- 549576 y- 5980692 Zone- 4 54 to Same Pool: 1222' to 1H-102L2 16. Deviated wells: Kickoff depth: 560 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92.36 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94# H40 Welded 80 40 40 120 120 16" 13-3/8" 68# L80 H563 1918 40 40 1918 1864 12-1/4" 9-5/8" 40# L80 H563 9987 40 40 9987 3912 6-3/4" 4-1/2" 12.6# L80 H563 6309 9161 3767 16249 3999 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): N/A 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: Chris Brillon Contact Email: trevor.kelley@conocophillips.com Wells Engineering Manager Contact Phone: (281) 513-6789 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : 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 Kuparuk River Field West Sak Oil Pool August 10th 2024 25636' to ADL025636 1432 sx of 14.0 ppg Ext. Class G + 346 sx of 15.3 ppg Class G 1074 sx of 11.0 ppg LiteCRETE + 328 sx of 15.8 ppg Class G Cement to surface with 10 yds slurry 1513 N/A:Open Hole Standalone Screens If checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Authorized Title: Authorized Signature: Trevor Kelley Commission Use Only See cover letter for other requirements. Perforation Depth MD (ft): Perforation Depth TVD (ft): N/A N/A N/A N/A N/A Casing Length Size Cement Volume MD Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): 18. Casing Program:Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks (including stage data) 1913 P.O. Box 100360 Anchorage, Alaska, 99510-0360 11 FNL, 766 FEL, S33 T12N R10E, UM ADL025636, ADL025637, ADL025639 ^dd K&>^< >^<K/>E'^KE^ Zsd/KEKDD/^^/KE PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips Alaska, Inc.59-52-180 KRU 1H-107 889 FSL, 1160 FEL, S22 T12N R10E, UM 931811000, 931812000, 931696000 150 FSL, 2137 FEL, S14 T12N R10E, UM 2560, 2560, 2560 GL / BF Elevation above MSL (ft): 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-onlysvy req'd: Yes No gjg Exploratory Oil Development Gas Service Supply Multiple Zone Geothermal No No &ŽƌŵϭϬͲϰϬϭZĞǀŝƐĞĚϯͬϮϬϮϭ This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Grace Christianson at 8:20 am, Jul 03, 2024 50-029-23795-00-00 VTL 7/30/2024 X 224-092 SFD 7/12/2024 2137' to KRU boundary. SFD DSR-7/8/24 Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig Annular preventer test to 2500 psig Surface casing LOT and annular LOT to the AOGCC as soon as available 13CR80 per T. Kelley, CPAI, 7/16/2024 SFD BOPE testing on a 21-day interval is approved with the attached conditions RAM configuration allowing three preventers for MPSP < 3000 psig is approved as outlined in 20 AAC 25.035.c.1.A for Int and production holes. ($8 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.31 14:12:56 -08'00' 07/31/24 07/31/24 RBDMS JSB 080224 KRU 1H-107 and 1H-107L1 CPAI’s request to allow BOPE testing on a 21-day interval is approved with the following conditions: - CPAI must continue to implement the Between Wells Maintenance Program as approved by AOGCC. - The initial test after rigging up BOPE to drill a well must be to the rated working pressure as provided in API Standard 53. - CPAI is encouraged to take advantage of opportunities to test within the 21-day time limit. - CPAI must adhere to original equipment manufacturer recommendations and replacement parts for BOPE. - Requests for extensions beyond 21 days must include justification with supporting information demonstrating the additional time is necessary for well control purposes or to mitigate a stuck drill string. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510-0360 Telephone 907-276-1215 July 2, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill 1H-107 Dear Sir or Madam, ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore West Sak B Sand – Dual Lateral Producer from the 1H drilling pad. The intended spud date for this well is August 10th 2024. It is intended that Doyon 25 be used to drill the well. 1H-107 will drill a 16" surface hole on diverter. 13-3/8'' casing will be run and cemented to surface. The remaining intervals will utilize Doyon 25’s 13-5/8” x 5000 psi BOP stack with required ram installations and tested on a 21 day cycle in accordance with ConocoPhillips and AOGCC policy. The 12-1/4'' intermediate hole section will be landed in the top of the West Sak B sand. 9-5/8'' intermediate casing will be run and cemented in place with a 500’ or 250’ TVD column of cement above the highest hydrocarbon bearing zone per AOGCC regulation. The lower 6-3/4'' West Sak B production lateral will be initiated and then directionally drilled to complete the 1H-107. The lateral will be geo-steered and completed with 4-1/2'' Open Hole Standalone Screens. A separate Permit to Drill application will be submitted for the 1H-107L1 wellbore. The upper 1H-107L1 6-3/4'' West Sak D production lateral will be geo- steered and completed with 4-1/2'' Open Hole Standalone Screens. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a) 2. Proposed drilling program 3. Proposed drilling fluids program summary 4. Proposed completion diagram 5. Pressure information as required by 20 ACC 25.005 (c) (4) (a-c) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Trevor Kelley at (281) 513-6789 (trevor.kelley@conocophillips.com) or Greg Hobbs at 907-263-4749 (greg.s.hobbs@conocophillips.com). Regards, Trevor Kelley Senior Drilling Engineer cc: 1H-107 Well File / Jenna Taylor ATO 1732 David Lee ATO 1552 Chris Brillon ATO 1548 West Sak B production lateral ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭWϭͮϭϯ ϭ,ͲϭϬϳtĞůůWůĂŶ ƉƉůŝĐĂƚŝŽŶĨŽƌWĞƌŵŝƚƚŽƌŝůů dĂďůĞŽĨŽŶƚĞŶƚƐ ϭ͘tĞůůEĂŵĞ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘Ϯ Ϯ͘>ŽĐĂƚŝŽŶ^ƵŵŵĂƌLJ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘Ϯ ϯ͘WƌŽƉŽƐĞĚƌŝůůŝŶŐWƌŽŐƌĂŵ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϱ ϰ͘ŝǀĞƌƚĞƌĂŶĚKW/ŶĨŽƌŵĂƚŝŽŶ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϲ ϱ͘D^WĂůĐƵůĂƚŝŽŶƐ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϳ ϲ͘WƌŽĐĞĚƵƌĞĨŽƌŽŶĚƵĐƚŝŶŐ&ŽƌŵĂƚŝŽŶ/ŶƚĞŐƌŝƚLJdĞƐƚƐ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϴ ϳ͘ĂƐŝŶŐĂŶĚĞŵĞŶƚŝŶŐWƌŽŐƌĂŵ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϴ ϴ͘ƌŝůůŝŶŐ&ůƵŝĚWƌŽŐƌĂŵ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϭϬ ϵ͘ďŶŽƌŵĂůůLJWƌĞƐƐƵƌĞĚ&ŽƌŵĂƚŝŽŶ/ŶĨŽƌŵĂƚŝŽŶ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϭϬ ϭϬ͘^ĞŝƐŵŝĐŶĂůLJƐŝƐ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϭϭ ϭϭ͘^ĞĂďĞĚŽŶĚŝƚŝŽŶŶĂůLJƐŝƐ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϭϭ ϭϮ͘ ǀŝĚĞŶĐĞŽĨŽŶĚŝŶŐ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϭϭ ϭϯ͘ŝƐĐƵƐƐŝŽŶŽĨDƵĚĂŶĚƵƚƚŝŶŐƐŝƐƉŽƐĂů͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϭϭ ϭϰ͘ƌŝůůŝŶŐ,ĂnjĂƌĚƐ^ƵŵŵĂƌLJ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϭϭ ϭϱ͘WƌŽƉŽƐĞĚŽŵƉůĞƚŝŽŶ^ĐŚĞŵĂƚŝĐ͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘͘ϭϯ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭWϮͮϭϯ ϭ͘ tĞůůEĂŵĞ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĨͿ dŚĞǁĞůůĨŽƌǁŚŝĐŚƚŚŝƐĂƉƉůŝĐĂƚŝŽŶŝƐƐƵďŵŝƚƚĞĚǁŝůůďĞĚĞƐŝŐŶ ĂƚĞĚĂƐϭ,ͲϭϬϳ Ϯ͘ >ŽĐĂƚŝŽŶ^ƵŵŵĂƌLJ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϮͿ >ŽĐĂƚŝŽŶĂƚ^ƵƌĨĂĐĞϭϭ&E>͕ϳϲϲ& >͕^ϯϯdϭϮEZϭϬ ͕hD EϮϳ EŽƌƚŚŝŶŐ͗ϱϵϴϬϲϵϮ͘ϯϭ ĂƐƚŝŶŐ͗ϱϰϵϱϳϱ͘ϱϮ Z< ůĞǀĂƚŝŽŶϯϵ͛D^> WĂĚ ůĞǀĂƚŝŽŶϱϰ͛D^> dŽƉŽĨWƌŽĚƵĐƚŝǀĞ,ŽƌŝnjŽŶ;,ĞĞůͿϴϴϵ&^>͕ϭϭϲϬ& >͕^ϮϮdϭϮEZϭϬ ͕hD EϮϳ EŽƌƚŚŝŶŐ͗ϱϵϴϲϵϬϱ͘ϱϲ ĂƐƚŝŶŐ͗ϱϱϰϰϬϲ͘ϵϲ DĞĂƐƵƌĞĚĞƉƚŚ͕Z<͗ϵϵϴϳ͚D dƌƵĞsĞƌƚŝĐĂůĞƉƚŚ͕Z<͗ϯϵϭϮ͚ds dƌƵĞsĞƌƚŝĐĂůĞƉƚŚ͕^^͗ϯϴϭϵ͚dsƐƐ dŽƚĂůĞƉƚŚ;dŽĞͿϭϱϬ&^>͕Ϯϭϯϳ& >͕^ϭϰdϭϮEZϭϬ ͕hD EϮϳ EŽƌƚŚŝŶŐ͗ϱϵϵϭϰϳϴ͘ϭϭ ĂƐƚŝŶŐ͗ϱϱϴϲϲϴ͘ϳϳ DĞĂƐƵƌĞĚĞƉƚŚ͕Z<͗ϭϲϮϰϵ͚D dƌƵĞsĞƌƚŝĐĂůĞƉƚŚ͕Z<͗ϯϵϵϵ͚ds dƌƵĞsĞƌƚŝĐĂůĞƉƚŚ͕^^͗ϯϵϬϲ͚dsƐƐ WůĞĂƐĞƐĞĞĂƚƚĂĐŚĞĚǁĞůůƐƚŝĐŬĚŝĂŐƌĂŵĨŽƌƚŚĞĐƵƌƌĞŶƚƉůĂŶŶĞĚĚĞǀĞůŽƉŵĞŶƚŽĨƚŚĞƉĂĚ͘ 93' SFD ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭWϯͮϭϯ WĂĚ>ĂLJŽƵƚ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭWϰͮϭϯ tĞůůWůĂƚ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭWϱͮϭϯ ϯ͘ WƌŽƉŽƐĞĚƌŝůůŝŶŐWƌŽŐƌĂŵ ϭ͘ D/ZhŽLJŽŶϮϱŽŶƚŽǁĞůůŽǀĞƌƉƌĞͲŝŶƐƚĂůůĞĚϮϬ͟ŝŶƐƵůĂƚĞĚĐŽŶĚƵĐ ƚŽƌ͘/ŶƐƚĂůůĚŝǀĞƌƚĞƌĂŶĚĨƵŶĐƚŝŽŶƚĞƐƚ͘ Ϯ͘ ZŝŐƵƉĂŶĚƚĞƐƚƌŝƐĞƌ͕ĚĞǁĂƚĞƌĐĞůůĂƌĂƐŶĞĞĚĞĚ͘ ϯ͘ ƌŝůůϭϲΗŚŽůĞƚŽƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐƉŽŝŶƚĂƐƉĞƌƚŚĞĚŝƌĞĐƚŝŽŶĂůƉůĂŶ͕ǁŝƚŚ^ƉƵĚDƵĚ͘;>tWƌŽŐƌĂŵ͗ 'ZͬZ ^ͬ'tͿ͘ ϰ͘ ZƵŶĂŶĚĐĞŵĞŶƚŶĞǁϭϯͲϯͬϴΖΖƐƵƌĨĂĐĞĐĂƐŝŶŐƚŽƐƵƌĨĂĐĞ͘ZĞƐƵůƚƐŽĨƚŚĞĐĞŵĞŶƚŽƉĞƌĂƚŝŽŶǁŝůůďĞ ƐƵďŵŝƚƚĞĚĂƐƐŽŽŶĂƐƉŽƐƐŝďůĞ͘ ϱ͘ /ŶƐƚĂůůKW ǁŝƚŚƚŚĞĨŽůůŽǁŝŶŐĞƋƵŝƉŵĞŶƚͬĐŽŶĨŝŐƵƌĂƚŝŽŶ͗ϭϯͲϱͬϴ͟ĂŶŶƵůĂƌƉƌĞǀĞŶƚĞƌ͕ϵͲϱͬϴΖΖ&Z͛Ɛ͕ ďůŝŶĚƌĂŵĂŶĚϮͲϳͬϴ͟džϱ͟sZ͛Ɛ͘ x ^ĞĞƐĞĐƚŝŽŶϰĨŽƌƌĂŵĐŽŶĨŝŐƵƌĂƚŝŽŶũƵƐƚŝĨŝĐĂƚŝŽŶ͘ ϲ͘ dĞƐƚKW ƚŽϮϱϬƉƐŝůŽǁͬϱϬϬϬƉƐŝŚŝŐŚ;ϮϰͲϰϴŚƌ͘ƌĞŐƵůĂƚŽƌLJŶŽƚŝĐĞͿ͘ ϳ͘ WŝĐŬƵƉĂŶĚƌƵŶŝŶŚŽůĞǁŝƚŚϭϮͲϭͬϰΖΖĚƌŝůůŝŶŐ,ƚŽĚƌŝůůŝŶƚ ĞƌŵĞĚŝĂƚĞηϭ͘ ϴ͘ ŚĂƌƚĐĂƐŝŶŐƉƌĞƐƐƵƌĞƚĞƐƚƚŽϯϱϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ͕ŝĨŶŽƚĂůƌĞĂĚLJĚŽŶĞŽŶƉůƵŐďƵŵƉ͘ ϵ͘ ƌŝůůŽƵƚƐŚŽĞƚƌĂĐŬĂŶĚϮϬ͛ŽĨŶĞǁŚŽůĞ͘ ϭϬ͘ ŝƐƉůĂĐĞǁĞůůƚŽ&tW͘ ϭϭ͘ WĞƌĨŽƌŵ>KdƚŽŵĂdžŝŵƵŵ DtŽĨϭϰƉƉŐ͘DŝŶŝŵƵŵ>KdƌĞƋƵŝƌĞĚƚŽĚƌŝůůĂŚĞĂĚŝƐϭϬ͘ϴƉƉŐ Dt͘ ϭϮ͘ ƌŝůůϭϮͲϭͬϰΖΖŚŽůĞƚŽƚŚĞĐĂƐŝŶŐƉŽŝŶƚ͘;>tWƌŽŐƌĂŵ͗'ZͬZ ^Ϳ͘ ϭϯ͘ ŝƌĐƵůĂƚĞǁĞůůďŽƌĞĐůĞĂŶĂŶĚWKK,͘ ϭϰ͘ ZƵŶϵͲϱͬϴΖΖŝŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐƚŽd͘ ϭϱ͘ WƵŵƉƐŝŶŐůĞƐƚĂŐĞĐĞŵĞŶƚũŽďƚŽŝƐŽůĂƚĞƚŚĞĐĂƐŝŶŐƐŚŽĞ͘WůĂŶŶĞĚƚŽƉϮϱϬΖdsĂďŽǀĞdͬhŐŶƵ͘dĞƐƚ ĐĂƐŝŶŐŽŶƉůƵŐďƵŵƉƚŽϯϱϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ͘ ϭϲ͘ ŚĂŶŐĞƵƉƉĞƌϵͲϱͬϴΖΖƐŽůŝĚďŽĚLJƌĂŵƐƚŽϮͲϳͬϴ͟džϱ͟sZ͛Ɛ͘dĞƐƚKW ƚŽϮϱϬƉƐŝͬϯϱϬϬƉƐŝ͘;ϮϰͲϰϴŚƌ͘ ƌĞŐƵůĂƚŽƌLJŶŽƚŝĐĞͿ͘ ϭϳ͘ WŝĐŬƵƉϴ͘ϱ͟ůĞĂŶŽƵƚ,ƚŽƉĞƌĨŽƌŵĐůĞĂŶŽƵƚŽĨƚŚĞƐŚŽĞƚƌĂĐŬ͘Z/,͘ ϭϴ͘ ŚĂƌƚĐĂƐŝŶŐƉƌĞƐƐƵƌĞƚĞƐƚƚŽϯϱϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐĂŶĚƌĞĐŽƌĚƌĞƐƵůƚƐ͕ŝĨŶŽƚĂůƌĞĂĚLJĚŽŶĞŽŶƉůƵŐ ďƵŵƉ͘ ϭϵ͘ ƌŝůůŽƵƚƐŚŽĞƚƌĂĐŬĂŶĚϮϬ͛ŽĨŶĞǁŚŽůĞ͘ŝƐƉůĂĐĞǁĞůůƚŽ&ůŽW ƌŽtD ϮϬ͘ WĞƌĨŽƌŵ&/dƚŽŵĂdžϭϯƉƉŐ Dt͘DŝŶŝŵƵŵƌĞƋƵŝƌĞĚƚŽĚƌŝůůĂŚĞĂĚŝƐϭϬ͘ϱƉƉŐ Dt͘ Ϯϭ͘ WŝĐŬƵƉĂŶĚƌƵŶŝŶŚŽůĞǁŝƚŚϲͲϯͬϰΖΖĚƌŝůůŝŶŐ,ƚŽĚƌŝůůƉƌŽĚ ƵĐƚŝŽŶŚŽůĞ;>tWƌŽŐƌĂŵ͗ 'ZͬZ ^ͬnjŝŵƵƚŚĂůZ ^ͬ EͬE h͕^KE/Ϳ͘^ŝŵKƉƐ͕ƉĞƌĨŽƌŵϵͲϱͬϴΖΖĂŶŶƵůƵƐĨƌĞĞnjĞƉƌŽƚĞĐƚ͘ ϮϮ͘ ƌŝůůϲͲϯͬϰΖΖŚŽƌŝnjŽŶƚĂůŚŽůĞƚŽdŽĨϭ,ͲϭϬϳĚŝƌĞĐƚŝŽŶĂůƉƌŽĨŝ ůĞ;>tWƌŽŐƌĂŵ͗'ZͬZ ^ͬnjŝŵƵƚŚĂů Z ^ͬ EͬE hͿ Ϯϯ͘ ŝƌĐƵůĂƚĞǁĞůůďŽƌĞĐůĞĂŶĂŶĚWKK,͘ per T. Kelley, CPAI, 7/16/2024 SFD ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭWϲͮϭϯ dƌĂŶƐĨĞƌĨƌŽŵϭ,ͲϭϮϬW,ϭWdƚŽϭ,ͲϭϮϬWd ϰ͘ ŝǀĞƌƚĞƌĂŶĚKW/ŶĨŽƌŵĂƚŝŽŶ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϯΘϳͿ WůĞĂƐĞƌĞĨĞƌĞŶĐĞKWĂŶĚĚŝǀĞƌƚĞƌƐĐŚĞŵĂƚŝĐƐŽŶĨŝůĞĨŽƌŽLJŽŶϮϱ͘ ŽLJŽŶϮϱǁŝůůƵƐĞĂKW ƐƚĂĐŬĞƋƵŝƉƉĞĚǁŝƚŚĂŶĂŶŶƵůĂƌƉƌĞǀĞŶƚĞƌ͕ĨŝdžĞĚ͕ϵͲϱͬϴΖΖƐŽůŝĚďŽĚLJƌĂŵƐ͕ ďůŝŶĚͬƐŚĞĂƌƌĂŵƐĂŶĚǀĂƌŝĂďůĞďŽƌĞƌĂŵƐǁŚŝůĞĚƌŝůůŝŶŐĂŶĚƌƵŶŶŝŶŐĐĂƐŝŶŐŝŶƚŚĞŝŶƚĞƌŵĞĚŝĂƚĞƐĞĐƚŝŽŶŽĨ ϭ,ͲϭϬϳ͘ ϭ,ͲϭϬϳŚĂƐĂD^WŽĨϭϱϭϯƉƐŝŝŶƚŚĞƉƌŽĚƵĐƚŝŽŶŚŽůĞƐĞĐƚŝŽŶƵƐ ŝŶŐƚŚĞŵĞƚŚŽĚŽůŽŐLJƉƌĞƐĞŶƚĞĚŝŶ ƐĞĐƚŝŽŶϱD^WĐĂůĐƵůĂƚŝŽŶƐ͘ ϮϬϮϱ͘Ϭϯϱ͘Ğ͘ϭ͗͘ &ŽƌĂŶŽƉĞƌĂƚŝŽŶǁŝƚŚĂŵĂdžŝŵƵŵƉŽƚĞŶƚŝĂůƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞŽĨϯ ͕ϬϬϬƉƐŝŽƌůĞƐƐ͕KW ŵƵƐƚŚĂǀĞĂƚůĞĂƐƚ ƚŚƌĞĞƉƌĞǀĞŶƚĞƌƐ͕ŝŶĐůƵĚŝŶŐ͗ ŝ͘ KŶĞĞƋƵŝƉƉĞĚǁŝƚŚƉŝƉĞƌĂŵƐƚŚĂƚĨŝƚƚŚĞƐŝnjĞŽĨĚƌŝůůƉŝƉĞ͕ƚƵ ďŝŶŐŽƌĐĂƐŝŶŐďĞŐŝŶƵƐĞĚ͕ĞdžĐĞƉƚƚŚĂƚƉŝƉĞƌĂŵƐ ŶĞĞĚŶŽƚďĞƐŝnjĞĚƚŽďŽƚƚŽŵͲŚŽůĞĂƐƐĞŵďůŝĞƐĂŶĚĚƌŝůůĐŽůůĂƌƐ͘ ŝŝ͘ KŶĞǁŝƚŚďůŝŶĚƌĂŵƐ ŝŝŝ͘ KŶĞĂŶŶƵůĂƌƚLJƉĞ /ŶƚĞƌŵĞĚŝĂƚĞƌŝůůŝŶŐͬĂƐŝŶŐ x ŶŶƵůĂƌWƌĞǀĞŶƚĞƌ;ŝŝŝͿ x ϵͲϱͬϴΖΖ&ŝdžĞĚZĂŵƐ x ůŝŶĚͬ^ŚĞĂƌZĂŵƐ;ŝŝͿ x sZ͛Ɛ;ŝͿ WƌŽĚƵĐƚŝŽŶ͗ x ŶŶƵůĂƌWƌĞǀĞŶƚĞƌ;ŝŝŝͿ x ^ŽůŝĚŽĚLJZĂŵƐ x ůŝŶĚͬ^ŚĞĂƌZĂŵƐ;ŝŝͿ x sZ͛Ɛ;ŝͿ sZ ? ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭWϳͮϭϯ ϱ͘ D^WĂůĐƵůĂƚŝŽŶƐ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϰͿ ;ͿŵĂdžŝŵƵŵĚŽǁŶŚŽůĞƉƌĞƐƐƵƌĞĂŶĚŵĂdžŝŵƵŵƉŽƚĞŶƚŝĂůƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞ͖ DĂdžŝŵƵŵWŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ;DW^WͿŝƐĚĞƚĞƌŵŝŶĞĚĂƐƚŚĞůĞƐƐĞƌŽĨ͗ DĞƚŚŽĚϭ͗ƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞĂƚďƌĞĂŬĚŽǁŶŽĨƚŚĞĨŽƌŵĂƚŝŽŶĐĂƐŝŶŐƐĞĂƚǁŝƚŚĂŐĂƐŐƌĂĚŝĞŶƚƚŽƚŚĞƐƵƌĨĂĐĞ DĞƚŚŽĚϮ͗ĨŽƌŵĂƚŝŽŶƉŽƌĞƉƌĞƐƐƵƌĞĂƚƚŚĞŶĞdžƚĐĂƐŝŶŐƉŽŝŶƚůĞƐƐĂŐĂƐŐƌĂĚŝĞŶƚƚŽƚŚĞƐƵƌĨĂĐĞ DĞƚŚŽĚϭDĞƚŚŽĚϮ ܯܲܵܲ ൌ ሾሺܨܩൈ ͲǤͲͷʹሻ െ ܩܽݏܩݎܽ݀݅݁݊ݐሿ ൈ ܸܶܦ ܯܲܵܲ ൌ ܨܲܲ െ ሺܩܽݏܩݎܽ݀݅݁݊ݐሻ ൈ ܸܶܦ tŚĞƌĞ͗ &'ʹ&ƌĂĐƚƵƌĞŐƌĂĚŝĞŶƚĂƚƚŚĞĐĂƐŝŶŐƐĞĂƚŝŶůďͬŐĂů Ϭ͘ϬϱϮʹŽŶǀĞƌƐŝŽŶĨƌŽŵůďͬŐĂůƚŽƉƐŝͬĨƚ 'ĂƐ'ƌĂĚŝĞŶƚʹϬ͘ϭƉƐŝͬĨƚ dsʹdƌƵĞsĞƌƚŝĐĂůĞƉƚŚŽĨĐĂƐŝŶŐƐĞĂƚŝŶĨƚZ< tŚĞƌĞ͗ &WWʹ&ŽƌŵĂƚŝŽŶWŽƌĞWƌĞƐƐƵƌĞĂƚƚŚĞŶĞdžƚĐĂƐŝŶŐƉŽŝŶƚ 'ĂƐ'ƌĂĚŝĞŶƚʹϬ͘ϭƉƐŝͬĨƚ dŚĞĨŽůůŽǁŝŶŐƉƌĞƐĞŶƚƐĚĂƚĂƵƐĞĚĨŽƌĐĂůĐƵůĂƚŝŽŶŽĨDĂdžŝŵƵŵWŽƚĞŶƚŝĂů^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ;DW^WͿǁŚŝůĞ ĚƌŝůůŝŶŐ͗ ^ĞĐƚŝŽŶ,ŽůĞ^ŝnjĞ WƌĞǀŝŽƵƐ^'^ĞĐƚŝŽŶdDW^W ƉƐŝ DW^WDW^W ^ŝnjĞDds&' ƉƉŐ WŽƌĞWƌĞƐƐƵƌĞ ƉƉŐͮƉƐŝDdsWŽƌĞWƌĞƐƐƵƌĞ ƉƉŐͮƉƐŝ DĞƚŚŽĚϭ ƉƐŝ DĞƚŚŽĚϮ ƉƐŝ ^hZ&ϭϲΗ ϮϬ ϴϬ ϴϬ ϭϮ͘ϱ ϴ͘ϲ ϯϲ ϭϵϭϴ ϭϴϲϰ ϴ͘ϲ ϴϯϰ ϰϰϰϰϲϰϴ /EdϭϮ͘Ϯϱ ϭϯ͘ϯϳϱ ϭϵϭϴ ϭϴϲϰ ϭϮ͘ϱ ϴ͘ϲ ϴϯϰ ϵϵϴϳ ϯϵϭϮ ϵ͘Ϯ ϭϴϳϮ ϭ͕ϬϮϱϭ͕ϬϮϱϭ͕ϰϴϬ WZKϲ͘ϳϱ ϰ͘ϱ ϵϵϴϳ ϯϵϭϮ ϭϮ͘ϱ ϵ͘Ϯ ϭϴϳϮ ϭϲϮϰϵ ϯϵϵϵ ϵ͘Ϯ ϭϵϭϯ ϭ͕ϱϭϯ Ϯ͕ϭϱϮϭ͕ϱϭϯ ;ͿĚĂƚĂŽŶƉŽƚĞŶƚŝĂůŐĂƐnjŽŶĞƐ͖ dŚĞǁĞůůďŽƌĞŝƐŶŽƚĞdžƉĞĐƚĞĚƚŽƉĞŶĞƚƌĂƚĞĂŶLJƐŚĂůůŽǁŐĂƐnjŽŶĞƐ͘ ;ͿĚĂƚĂĐŽŶĐĞƌŶŝŶŐƉŽƚĞŶƚŝĂůĐĂƵƐĞƐŽĨŚŽůĞƉƌŽďůĞŵƐƐƵĐŚĂƐĂďŶŽƌŵĂůůLJŐĞŽͲƉƌĞƐƐƵƌĞĚƐƚƌĂƚĂ͕ůŽƐƚ ĐŝƌĐƵůĂƚŝŽŶnjŽŶĞƐ͕ĂŶĚnjŽŶĞƐƚŚĂƚŚĂǀĞĂƉƌŽƉĞŶƐŝƚLJĨŽƌĚŝĨĨĞƌĞŶƚŝĂůƐƚŝĐŬŝŶŐ͖ WůĞĂƐĞƐĞĞƌŝůůŝŶŐ,ĂnjĂƌĚƐ^ƵŵŵĂƌLJ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭWϴͮϭϯ ϲ͘ WƌŽĐĞĚƵƌĞĨŽƌŽŶĚƵĐƚŝŶŐ&ŽƌŵĂƚŝŽŶ/ŶƚĞŐƌŝƚLJdĞƐƚƐ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϱͿ ƌŝůůŽƵƚĐĂƐŝŶŐƐŚŽĞĂŶĚƉĞƌĨŽƌŵ>KdƚĞƐƚŽƌ&/dŝŶĂĐĐŽƌĚĂŶĐĞ ǁŝƚŚƚŚĞ>Kdͬ&/dƉƌŽĐĞĚƵƌĞƚŚĂƚ ŽŶŽĐŽWŚŝůůŝƉƐůĂƐŬĂŚĂƐŽŶĨŝůĞǁŝƚŚƚŚĞŽŵŵŝƐƐŝŽŶ͘ ϳ͘ ĂƐŝŶŐĂŶĚĞŵĞŶƚŝŶŐWƌŽŐƌĂŵ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϲͿ ĂƐŝŶŐĂŶĚĞŵĞŶƚŝŶŐWƌŽŐƌĂŵ K ;ŝŶͿ ,ŽůĞ^ŝnjĞ ;ŝŶͿ tĞŝŐŚƚ ;ůďͬĨƚͿ'ƌĂĚĞŽŶŶ͘ĞŵĞŶƚWƌŽŐƌĂŵ ϮϬ ϰϮ ϵϰ ,ϰϬ tĞůĚĞĚ ĞŵĞŶƚĞĚƚŽƐƵƌĨĂĐĞǁŝƚŚ ϭϬLJĚƐƐůƵƌƌLJ ϭϯͲϯͬϴΖΖ ϭϲΗ ϲϴη >ϴϬ ,ϱϲϯ ĞŵĞŶƚƚŽ^ƵƌĨĂĐĞ ϵͲϱͬϴΖΖ ϭϮͲϭͬϰΖΖ ϰϬη >ϴϬ ,ϱϲϯ ϮϱϬΖdsĂďŽǀĞdͬhŐŶƵ ϰͲϭͬϮΖΖ ϲͲϯͬϰΖΖ ϭϮ͘ϲη >ϴϬ ,ϱϲϯ ƵŶůŝŶĞĚ ϭϯͲϯͬϴΖΖ^ƵƌĨĂĐĞĂƐŝŶŐƌƵŶƚŽϭϵϭϴΖDͬϭϴϲϰΖdsĞŵĞŶƚWůĂŶ͗ ĞŵĞŶƚĨƌŽŵϭϵϭϴ͛DƚŽϭϰϭϴ͛;ϱϬϬ͛ŽĨƚĂŝůͿǁŝƚŚůĂƐƐ'нĚĚƐΛϭϱ͘ϴƉƉŐ͕ĂŶĚĨƌŽŵϭϰϭϴΖƚŽƐƵƌĨĂĐĞ ǁŝƚŚϭϭ͘ϬƉƉŐ>ŝƚĞZ d ͘ƐƐƵŵĞϮϱϬйĞdžĐĞƐƐĂŶŶƵůĂƌǀŽůƵŵĞŝŶƚŚĞůĞĂĚĂŶĚϱϬйŝŶƚŚĞƚĂŝů͕njĞƌŽĞdžĐĞƐƐ ŝŶϮϬ͟ĐŽŶĚƵĐƚŽƌ͘ >ĞĂĚϯϲϱďďůƐсхϭϬϳϰƐdžŽĨϭϭ͘ϬƉƉŐ>ŝƚĞZ d нĚĚΖƐΛϭ͘ϵϭĨƚϹͬƐŬ dĂŝůϲϴďďůƐсхϯϮϴƐdžŽĨϭϱ͘ϴƉƉŐůĂƐƐ'нĚĚΖƐΛϭ͘ϭϲϱĨƚϹͬƐŬ ϵͲϱͬϴΖΖ/ŶƚĞƌŵĞĚŝĂƚĞ>ŝŶĞƌƌƵŶƚŽϵϵϴϳΖDͬϯϵϭϮΖdsĞŵĞŶƚWůĂŶ͗ ĞŵĞŶƚĨƌŽŵϵϵϴϳ͛DƚŽϴϵϴϳ͛D;ϭϬϬϬ͛ŽĨƚĂŝůͿǁŝƚŚůĂƐƐ'нĚĚƐΛϭϱ͘ϯƉƉŐ͕ĂŶĚĨƌŽŵϴϵϴϳ͛DƚŽ Εϯϯϯϱ͛DǁŝƚŚϭϰ͘ϬƉƉŐĞdžƚĞŶĚĞĚĐůĂƐƐ' džƚ͘ůĂƐƐ'͘dŽƉŽĨƐůƵƌƌLJŝƐĚĞƐŝŐŶĞĚƚŽďĞĂƚϯϯϯϱΖDͬϮϴϬϰΖ ds͕ǁŚŝĐŚŝƐϮϱϬΖdsĂďŽǀĞdͬhŐŶƵ͘ƐƐƵŵĞϮϱйĞdžĐĞƐƐĂŶŶƵůĂƌǀŽůƵŵĞŝŶƚŚĞůĞĂĚĂŶĚϮϱйŝŶƚŚĞ ƚĂŝů͘ >ĞĂĚϯϵϰďďůƐсхϭϰϯϮƐdžŽĨϭϰ͘ϬƉƉŐ džƚ͘ůĂƐƐ'нĚĚΖƐΛϭ͘ϱϰϱĨƚϹͬƐŬ dĂŝůϳϲďďůƐсхϯϰϲƐdžŽĨϭϱ͘ϯƉƉŐůĂƐƐ'нĚĚΖƐΛϭ͘ϮϯĨƚϹͬƐŬ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭWϲͬϲͬϮϬϮϰϭ,ͲϭϬϳK'ϭϬͲϰϬϭWϵͮϭϯtĞŝŐŚƚ zŝĞůĚĨƚϯďďůƐĨƚϯďďůƐĨƚϯďďůƐĨƚϯďďůƐƉƉŐĨƚϯͬ^ĂĐŬ>ĞĂĚ͗ŽŶĚƵĐƚŽƌ ϬΖͲϴϬΖ ϴϬ Ϭ͘ϭϴϮ Ϭй ϴϮ ϭϰ͘ϱϮ Ϭ Ϭ͘ϬϬ Ϭ Ϭ ϴϮ ϭϰ͘ϱϮ ϰϯ ϭϭ͘ϬƉƉŐ>ŝƚĞZ d ϭ͘ϵϭϬ>ĞĂĚ͗dŚƌƵWĞƌŵ ϴϬΖͲϭϰϭϴΖ ϭϯϯϴ Ϭ͘Ϭϳϱ ϮϱϬй ϱϲϯ ϭϬϬ͘Ϯϯ ϭϰϬϳ ϮϱϬ͘ϱϲ Ϭ Ϭ ϭϵϳϬ ϯϱϬ͘ϳϵ ϭϬϯϭ ϭϭ͘ϬƉƉŐ >ŝƚĞZ d ϭ͘ϵϭϬϲϰϰ ϭϭϰ͘ϳϱ ϭϰϬϳ ϮϱϬ͘ϱϲ Ϭ ϬϮϬϱϭ ϯϲϱ͘ϯϭ ϭϬϳϰ ϭϭ͘ϬƉƉŐ >ŝƚĞZ d ϭ͘ϵϭtĞŝŐŚƚ zŝĞůĚĨƚϯďďůƐĨƚϯďďůƐĨƚϯďďůƐĨƚϯďďůƐƉƉŐĨƚϯͬ^ĂĐŬdĂŝů͗ϱϬϬΖ ϭϰϭϴΖͲϭϵϭϴΖ ϱϬϬ Ϭ͘Ϭϳϱ ϱϬй ϮϭϬ ϯϳ͘ϰϱ ϭϬϱ ϭϴ͘ϳϯ Ϭ Ϭ ϯϭϱ ϱϲ͘ϭϴ Ϯϳϭϭϱ͘ϴƉƉŐ ůĂƐƐ' ϭ͘ϭϲϱdĂŝů͗^ŚŽĞdƌĂĐŬ ϭϴϯϴΖͲϭϵϭϴΖ ϴϬ Ϭ͘ϭϱϬ Ϭй ϲϳ ϭϭ͘ϵϴ Ϭ Ϭ͘ϬϬ Ϭ Ϭ ϲϳ ϭϭ͘ϵϴ ϱϴ ϭϱ͘ϴƉƉŐ ůĂƐƐ' ϭ͘ϭϲϱϮϳϴ ϰϵ͘ϰϯ ϭϬϱ ϭϴ͘ϳϯ Ϭ Ϭϯϴϯ ϲϴ͘ϭϲ ϯϮϴ ϭϱ͘ϴƉƉŐ ůĂƐƐ' ϭ͘ϭϲϱtĞŝŐŚƚ zŝĞůĚĨƚϯďďůƐĨƚϯďďůƐĨƚϯďďůƐĨƚϯďďůƐƉƉŐĨƚϯͬ^ĂĐŬ>ĞĂĚ >ĞĂĚ͗ϮϱϬΖdsĂďŽǀĞdͬhŐŶƵ ϯϯϯϱΖͲϴϵϴϳΖ ϱϲϱϮ Ϭ͘Ϭϱϲ Ϯϱй ϭϳϳϬϯϭϱ͘Ϯϴ ϰϰϯ ϳϴ͘ϴϮ Ϭ Ϭ ϮϮϭϯ ϯϵϰ͘ϭϬ ϭϰϯϮ ϭϰ͘ϬƉƉŐ džƚ͘ůĂƐƐ' ϭ͘ϱϰϱϭϳϳϬ ϯϭϱ͘Ϯϴ ϰϰϯ ϳϴ͘ϴϮ Ϭ ϬϮϮϭϯ ϯϵϰ͘ϭϬ ϭϰϯϮ ϭϰ͘ϬƉƉŐ džƚ͘ůĂƐƐ' ϭ͘ϱϰϱtĞŝŐŚƚ zŝĞůĚĨƚϯďďůƐĨƚϯďďůƐĨƚϯďďůƐĨƚϯďďůƐƉƉŐĨƚϯͬ^ĂĐŬdŽƉdĂŝů;ϭϬϬϬΖdĂŝůŽǀĞƌĂŐĞͿƚŽ^ŚŽĞ ϴϵϴϳΖͲϵϵϴϳΖ ϭϬϬϬ Ϭ͘Ϭϱϲ Ϯϱйϯϭϯ ϱϱ͘ϳϴ ϳϴ ϭϯ͘ϵϱ Ϭ Ϭ ϯϵϭ ϲϵ͘ϳϯ ϯϭϴ ϭϱ͘ϯƉƉŐ ůĂƐƐ' ϭ͘ϮϯϬ^ŚŽĞdƌĂĐŬ ϵϵϬϳΖͲϵϵϴϳΖ ϴϬ Ϭ͘Ϭϳϲ Ϭй ϯϰ ϲ͘Ϭϳ Ϭ Ϭ͘ϬϬ Ϭ Ϭ ϯϰ ϲ͘Ϭϳ Ϯϴ ϭϱ͘ϯƉƉŐ ůĂƐƐ' ϭ͘ϮϯϬϯϰϳ ϲϭ͘ϴϱ ϳϴ ϭϯ͘ϵϱ Ϭ ϬϰϮϲ ϳϱ͘ϳϵ ϯϰϲ ϭϱ͘ϯƉƉŐ ůĂƐƐ' ϭ͘ϮϯdĂŝůdŽƚĂůdĂŝůsŽůƵŵĞсϲϵ͘ϳϯнϲ͘ϬϳďďůƐсϳϱ͘ϳϵďďůƐсхϯϰϲƐdžŽĨϭϱ͘ϯƉƉŐůĂƐƐ'Λϭ͘ϮϯĨƚϹͬƐŬy^sŽůƵŵĞ ĚĚŝƚŝŽŶĂůďďůƐ dŽƚĂůsŽůƵŵĞ^ĂĐŬƐ ůĞŶĚWůĂĐĞŵĞŶƚ &ŽŽƚĂŐĞ ďďůͬĨƚ й džĐĞƐƐsŽůƵŵĞ y^sŽůƵŵĞ ĚĚŝƚŝŽŶĂůďďůƐ dŽƚĂůsŽůƵŵĞ^ĂĐŬƐ ůĞŶĚdŽƚĂů>ĞĂĚsŽůƵŵĞсϯϵϰ͘ϭϬďďůƐсхϭ͕ϰϯϮƐdžŽĨϭϰ͘ϬƉƉŐ džƚ͘ůĂƐƐ'Λϭ͘ϱϰϱĨƚϹͬƐŬWůĂĐĞŵĞŶƚ &ŽŽƚĂŐĞ ďďůͬĨƚ й džĐĞƐƐsŽůƵŵĞďďůͬĨƚ й džĐĞƐƐsŽůƵŵĞ y^sŽůƵŵĞ ĚĚŝƚŝŽŶĂůďďůƐy^sŽůƵŵĞ ĚĚŝƚŝŽŶĂůďďůƐ dŽƚĂůsŽůƵŵĞ^ĂĐŬƐ ůĞŶĚdŽƚĂůsŽůƵŵĞ^ƵƌĨĂĐĞ/ŶƚĞƌŵĞĚŝĂƚĞdĂŝůdŽƚĂů>ĞĂĚsŽůƵŵĞсϭϰ͘ϱϮнϯϱϬ͘ϳϵďďůƐсϯϲϱ͘ϯϭďďůƐсхϭ͕ϬϳϰƐdžŽĨϭϭ͘ϬƉƉŐ>ŝƚĞZ d Λϭ͘ϵϭĨƚϹͬƐŬ&ŽŽƚĂŐĞ&ŽŽƚĂŐĞ>ĞĂĚWůĂĐĞŵĞŶƚdŽƚĂůdĂŝůsŽůƵŵĞсϱϲ͘ϭϴнϭϭ͘ϵϴďďůƐсϲϴ͘ϭϲďďůƐсхϯϮϴƐdžŽĨϭϱ͘ϴƉƉŐůĂƐƐ'Λϭ͘ϭϲϱĨƚϹͬƐŬ^ĂĐŬƐ ůĞŶĚWůĂĐĞŵĞŶƚ ďďůͬĨƚ й džĐĞƐƐsŽůƵŵĞ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳϭϬͲϰϬϭWϭϬͮϭϯ ϴ͘ ƌŝůůŝŶŐ&ůƵŝĚWƌŽŐƌĂŵ ;ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϴͿͿ ^ƵƌĨĂĐĞ/ŶƚĞƌŵĞĚŝĂƚĞWƌŽĚƵĐƚŝŽŶ ,ŽůĞ^ŝnjĞŝŶϭϲΗ ϭϮͲϭͬϰΖΖ ϲͲϯͬϰΖΖ ĂƐŝŶŐ^ŝnjĞŝŶϭϯͲϯͬϴΖΖ ϵͲϱͬϴΖΖ ϰͲϭͬϮΖΖ DƵĚ^LJƐƚĞŵ^ƉƵĚDƵĚ &tW &ůŽWƌŽ ĂƐĞ&ůƵŝĚtD tD tD ĞŶƐŝƚLJƉƉŐϴ͘ϴͲϵ͘ϱƉƉŐ ϵ͘ϮƉƉŐ ϵ͘ϮƉƉŐ WsĐW>W >W >W zWůďͬ͘ϭϬϬĨƚϮϯϬͲϴϬ ϮϬͲϯϬ ϭϱͲϯϬ &ƵŶŶĞůsŝƐĐŽƐŝƚLJƐͬƋƚϭϬϬͲϯϬϬ Eͬ Eͬ /ŶŝƚŝĂů'ĞůƐůďͬ͘ϭϬϬĨƚϮϯϬͲϱϬ ϴͲϭϱ ϭϬ ϭϬDŝŶƵƚĞ'ĞůƐůďͬ͘ϭϬϬĨƚϮϯϬͲϱϬ фϯϬ ϭϱ W/&ůƵŝĚ>ŽƐƐĐĐͬϯϬŵŝŶE͘͘ фϭϬ ϰ ,W,d&ůƵŝĚ>ŽƐƐĐĐͬϯϬŵŝŶEͬ Eͬ ϭϬ Ɖ,ϵ͘ϬͲϭϬ͘Ϭ ϵ͘ϬͲϭϬ͘Ϭ ϵ͘Ϭʹϵ͘ϱ ^ƵƌĨĂĐĞ,ŽůĞ͗ ĨƌĞƐŚǁĂƚĞƌ^ƉƵĚDƵĚǁŝůůďĞƵƐĞĚĨŽƌƚŚĞƐƵƌĨĂĐĞŝŶƚĞƌǀĂů͘<ĞĞƉĨůŽǁůŝŶĞǀŝƐĐŽƐŝƚLJĂƚцϮϬϬƐĞĐͬƋƚǁŚŝůĞ ĚƌŝůůŝŶŐĂŶĚƌƵŶŶŝŶŐĐĂƐŝŶŐ͘ZĞĚƵĐĞǀŝƐĐŽƐŝƚLJƉƌŝŽƌƚŽĐĞŵĞŶƚŝŶŐ͘DĂŝŶƚĂŝŶŵƵĚǁĞŝŐŚƚϴ͘ϴͲϵ͘ϱƉƉŐďLJƵƐĞ ŽĨƐŽůŝĚƐĐŽŶƚƌŽůƐLJƐƚĞŵĂŶĚĚŝůƵƚŝŽŶƐǁŚĞƌĞŶĞĐĞƐƐĂƌLJ͘ /ŶƚĞƌŵĞĚŝĂƚĞ͗ &ƌĞƐŚǁĂƚĞƌƉŽůLJŵĞƌŵƵĚƐLJƐƚĞŵ͘ ŶƐƵƌĞŐŽŽĚŚŽůĞĐůĞĂŶŝŶŐďLJƉƵŵƉŝŶŐƌĞŐƵůĂƌƐǁĞĞƉƐĂŶĚŵĂdžŝŵŝnjŝŶŐ ĨůƵŝĚĂŶŶƵůĂƌǀĞůŽĐŝƚLJ͘DĂŝŶƚĂŝŶŵƵĚǁĞŝŐŚƚĨƌŽŵϵ͘ϮƉƉŐĂŶĚďĞ ƉƌĞƉĂƌĞĚƚŽĂĚĚůŽƐƐĐŝƌĐƵůĂƚŝŽŶ ŵĂƚĞƌŝĂůƐĂƐŶĞĞĚĞĚŝĨŶĞĐĞƐƐĂƌLJ͘'ŽŽĚĨŝůƚĞƌĐĂŬĞƋƵĂůŝƚLJ͕ŚŽůĞĐůĞĂŶŝŶŐĂŶĚŵĂŝŶƚĞŶĂŶĐĞŽĨůŽǁĚƌŝůů ƐŽůŝĚƐ;ďLJĚŝůƵƚŝŶŐĂƐŶĞĞĚĞĚͿǁŝůůĂůůďĞŝŵƉŽƌƚĂŶƚŝŶŵĂŝŶƚĂŝ ŶŝŶŐǁĞůůďŽƌĞƐƚĂďŝůŝƚLJ͘ WƌŽĚƵĐƚŝŽŶ,ŽůĞ͗ dŚĞŚŽƌŝnjŽŶƚĂůƉƌŽĚƵĐƚŝŽŶŝŶƚĞƌǀĂůǁŝůůďĞĚƌŝůůĞĚǁŝƚŚǁĂƚĞƌͲď ĂƐĞĚŵƵĚĚƌŝůůͲŝŶĨůƵŝĚǁĞŝŐŚƚĞĚƚŽϵ͘ϮƉƉŐ͘ ŝĂŐƌĂŵŽĨŽLJŽŶϮϱDƵĚ^LJƐƚĞŵŽŶĨŝůĞ͘ƌŝůůŝŶŐĨůƵŝĚƉƌĂĐƚŝĐĞ ƐǁŝůůďĞŝŶĂĐĐŽƌĚĂŶĐĞǁŝƚŚĂƉƉƌŽƉƌŝĂƚĞ ƌĞŐƵůĂƚŝŽŶƐ͘ ϵ͘ ďŶŽƌŵĂůůLJWƌĞƐƐƵƌĞĚ&ŽƌŵĂƚŝŽŶ/ŶĨŽƌŵĂƚŝŽŶ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϵͿ EͬͲƉƉůŝĐĂƚŝŽŶŝƐŶŽƚĨŽƌĂŶĞdžƉůŽƌĂƚŽƌLJŽƌƐƚƌĂƚŝŐƌĂƉŚŝĐƚĞƐƚǁĞůů͘ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳϭϬͲϰϬϭWϭϭͮϭϯ ϭϬ͘ ^ĞŝƐŵŝĐŶĂůLJƐŝƐ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϭϬͿ EͬͲƉƉůŝĐĂƚŝŽŶŝƐŶŽƚĨŽƌĂŶĞdžƉůŽƌĂƚŽƌLJŽƌƐƚƌĂƚŝŐƌĂƉŚŝĐƚĞƐƚǁĞůů͘ ϭϭ͘ ^ĞĂďĞĚŽŶĚŝƚŝŽŶŶĂůLJƐŝƐ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϭϭͿ EͬͲƉƉůŝĐĂƚŝŽŶŝƐŶŽƚĨŽƌĂŶŽĨĨƐŚŽƌĞǁĞůů͘ ϭϮ͘ ǀŝĚĞŶĐĞŽĨŽŶĚŝŶŐ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϭϮͿ ǀŝĚĞŶĐĞŽĨďŽŶĚŝŶŐĨŽƌŽŶŽĐŽWŚŝůůŝƉƐůĂƐŬĂ͕/ŶĐ͘ŝƐŽŶĨŝůĞǁŝƚŚƚŚĞŽŵŵŝƐƐŝŽŶ͘ ϭϯ͘ ŝƐĐƵƐƐŝŽŶŽĨDƵĚĂŶĚƵƚƚŝŶŐƐŝƐƉŽƐĂů ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϭϰͿ tĂƐƚĞĨůƵŝĚƐĂŶĚĐƵƚƚŝŶŐƐŐĞŶĞƌĂƚĞĚĚƵƌŝŶŐƚŚĞĚƌŝůůŝŶŐƉƌŽĐĞƐƐǁŝůůďĞĚŝƐƉŽƐĞĚŽĨďLJŚĂƵůŝŶŐƚŚĞĨůƵŝĚƐƚŽ Ă<ZhůĂƐƐ//ĚŝƐƉŽƐĂůǁĞůůĂƚƚŚĞϭĨĂĐŝůŝƚLJ͘/ĨŶĞĞĚĞĚ͕ĞdžĐĞƐƐĐƵƚƚŝŶŐƐŐĞŶĞƌĂƚĞĚǁŝůůďĞŚĂƵůĞĚƚŽDŝůŶĞ WŽŝŶƚŽƌWƌƵĚŚŽĞĂLJ'ƌŝŶĚĂŶĚ/ŶũĞĐƚ&ĂĐŝůŝƚLJĨŽƌƚĞŵƉŽƌĂƌLJƐƚŽƌĂŐĞĂŶĚĞǀĞŶƚƵĂůƉƌŽĐĞƐƐŝŶŐĨŽƌŝŶũĞĐƚŝŽŶ ĚŽǁŶĂŶĂƉƉƌŽǀĞĚĚŝƐƉŽƐĂůǁĞůů͕ŽƌƐƚŽƌĞĚ͕ƚĞƐƚĞĚĨŽƌŚĂnjĂƌĚŽƵƐ ƐƵďƐƚĂŶĐĞƐ͕ĂŶĚ;ŝĨĨƌĞĞŽĨŚĂnjĂƌĚŽƵƐ ƐƵďƐƚĂŶĐĞƐͿƵƐĞĚŽŶƉĂĚƐĂŶĚƌŽĂĚƐŝŶƚŚĞ<ƵƉĂƌƵŬĂƌĞĂŝŶĂĐĐŽƌĚĂŶĐĞǁŝƚŚĂƉĞƌŵŝƚĨƌŽŵƚŚĞ^ƚĂƚĞŽĨ ůĂƐŬĂ͘ ϭϰ͘ ƌŝůůŝŶŐ,ĂnjĂƌĚƐ^ƵŵŵĂƌLJ ϭϲΗ,ŽůĞͮϭϯͲϯͬϴΖΖĂƐŝŶŐ/ŶƚĞƌǀĂů ǀĞŶƚZŝƐŬ>ĞǀĞůDŝƚŝŐĂƚŝŽŶ^ƚƌĂƚĞŐLJ ƌŽĂĐŚŽĨŽŶĚƵĐƚŽƌ>Žǁ DŽŶŝƚŽƌĐĞůůĂƌĐŽŶƚŝŶƵŽƵƐůLJĚƵƌŝŶŐŝŶƚĞƌǀĂů͘ 'ĂƐ,LJĚƌĂƚĞƐDŽĚĞƌĂƚĞ ZĞĚƵĐĞĚƉƵŵƉƌĂƚĞƐ͕ZĞĚƵĐĞĚĚƌŝůůŝŶŐĨůƵŝĚƚĞŵƉĞƌĂƚƵƌĞƐ͕ĚĚŝƚŝŽŶƐŽĨ^ĐƌĞĞŶ<ůĞĞŶ ZƵŶŶŝŶŐ^ĂŶĚƐĂŶĚ'ƌĂǀĞůƐ>Žǁ DĂŝŶƚĂŝŶƉůĂŶŶĞĚŵƵĚƉĂƌĂŵĞƚĞƌƐ͕/ŶĐƌĞĂƐĞŵƵĚǁĞŝŐŚƚ͕ƵƐĞǁĞŝŐŚƚĞĚƐǁĞĞƉƐ͘ ,ŽůĞƐǁĂďďŝŶŐŽŶƚƌŝƉƐDŽĚĞƌĂƚĞ dƌŝƉƐƉĞĞĚƐ͕ƉƌŽƉĞƌŚŽůĞĨŝůůŝŶŐ;ƵƐĞŽĨƚƌŝƉƐŚĞĞƚƐͿ͕ƉƵŵƉŝŶŐŽƵƚ tĂƐŚŽƵƚƐͬ,ŽůĞ^ůŽƵŐŚŝŶŐ>Žǁ ŽŽůŵƵĚƚĞŵƉĞƌĂƚƵƌĞƐ͕ŵŝŶŝŵŝnjĞĐŝƌĐƵůĂƚŝŶŐƚŝŵĞƐǁŚĞŶƉŽƐƐŝďůĞ ŶƚŝͲŽůůŝƐŝŽŶDŽĚĞƌĂƚĞ&ŽůůŽǁƌĞĂůƚŝŵĞƐƵƌǀĞLJƐǀĞƌLJĐůŽƐĞůLJ͕ƐŚƵƚŝŶŶĞĂƌďLJǁĞůůƐƚŚĂƚǁĞŚĂǀĞĐŽůůŝƐŝŽŶĐŽŶĐĞƌŶƐ ǁŝƚŚ͕ŐLJƌŽƐƵƌǀĞLJƚŽĞŶƐƵƌĞƐƵƌǀĞLJĂĐĐƵƌĂĐLJ͘ ϭϮͲϭͬϰΖΖ,ŽůĞͮϵͲϱͬϴΖΖĂƐŝŶŐ/ŶƚĞƌǀĂů ǀĞŶƚZŝƐŬ>ĞǀĞůDŝƚŝŐĂƚŝŽŶ^ƚƌĂƚĞŐLJ ZƵŶŶŝŶŐ^ĂŶĚƐĂŶĚ'ƌĂǀĞůƐ>Žǁ DĂŝŶƚĂŝŶƉůĂŶŶĞĚŵƵĚƉĂƌĂŵĞƚĞƌƐ͕ŝŶĐƌĞĂƐĞŵƵĚǁĞŝŐŚƚ͕ƵƐĞǁĞŝŐŚƚĞĚƐǁĞĞƉƐ͘ ^ƚƵĐŬWŝƉĞ>Žǁ'ŽŽĚŚŽůĞĐůĞĂŶŝŶŐ͕ƉƌĞͲƚƌĞĂƚŵĞŶƚǁŝƚŚůŽƐƚĐŝƌĐƵůĂƚŝŽŶŵĂƚĞƌŝĂů͕ƐƚĂďŝůŝnjĞĚ,͕ ĚĞĐƌĞĂƐĞĚŵƵĚǁĞŝŐŚƚ͘ ďŶŽƌŵĂůZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞ>Žǁ KWƚƌĂŝŶŝŶŐĂŶĚĚƌŝůůƐ͕ŝŶĐƌĞĂƐĞĚŵƵĚǁĞŝŐŚƚ͘ >ŽƐƚĐŝƌĐƵůĂƚŝŽŶDŽĚĞƌĂƚĞ ZĞĚƵĐĞĚƉƵŵƉƌĂƚĞƐ͕ŵƵĚƌŚĞŽůŽŐLJ͕>D͘ ,ŽůĞƐǁĂďďŝŶŐŽŶƚƌŝƉƐDŽĚĞƌĂƚĞ dƌŝƉƐƉĞĞĚƐ͕ƉƌŽƉĞƌŚŽůĞĨŝůůŝŶŐ;ƵƐĞŽĨƚƌŝƉƐŚĞĞƚƐͿ͕ƉƵŵƉŝŶŐŽƵƚ͘ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳϭϬͲϰϬϭWϭϮͮϭϯ ϲͲϯͬϰΖΖ,ŽůĞͮϰͲϭͬϮΖΖ>ŝŶĞƌͲ,ŽƌŝnjŽŶƚĂůWƌŽĚƵĐƚŝŽŶ,ŽůĞ ǀĞŶƚZŝƐŬ>ĞǀĞůDŝƚŝŐĂƚŝŽŶ^ƚƌĂƚĞŐLJ ďŶŽƌŵĂůZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞ>Žǁ ^ƚƌŝƉƉŝŶŐĚƌŝůůƐ͕ƐŚƵƚͲŝŶĚƌŝůůƐ͕ŝŶĐƌĞĂƐĞĚŵƵĚǁĞŝŐŚƚ͘ ^ƚƵĐŬWŝƉĞ>Žǁ'ŽŽĚŚŽůĞĐůĞĂŶŝŶŐ͕WtƚŽŽůƐŵŽŶŝƚŽƌŝŶŐĂŶĚĂŶĂůLJƐŝƐ͕ĚĞĐƌĞĂƐĞĚŵƵĚǁĞŝŐŚƚŝĨ ƉŽƐƐŝďůĞŝĨƉŝƉĞĚŽĞƐŐĞƚƐƚƵĐŬ͘ >ŽƐƚŝƌĐƵůĂƚŝŽŶDŽĚĞƌĂƚĞZĞĚƵĐĞĚƉƵŵƉƌĂƚĞƐ͕ŵƵĚƌŚĞŽůŽŐLJ͕>DƉƌŽŐƌĂŵ͕ĂĚĚŝƚŝŽŶĂůĨůƵŝĚƐƚŽƌĞĚŽŶůŽĐĂƚŝŽŶ ĚƵƌŝŶŐĐŽŵƉůĞƚŝŽŶƌƵŶ͘ ŝĨĨĞƌĞŶƚŝĂů^ƚŝĐŬŝŶŐDŽĚĞƌĂƚĞ &ŽůůŽǁŵƵĚƉƌŽŐƌĂŵ͕ŬĞĞƉƉŝƉĞŵŽǀŝŶŐǁŚĞŶĂďůĞ͘ ,ŽůĞ^ǁĂďďŝŶŐŽŶdƌŝƉƐDŽĚĞƌĂƚĞ dƌŝƉƐƉĞĞĚƐ͕ƉƌŽƉĞƌŚŽůĞĨŝůůŝŶŐ;ƵƐĞŽĨƚƌŝƉƐŚĞĞƚƐͿ͕ƉƵŵƉŝŶŐŽƵƚŽƌďĂĐŬƌĞĂŵŝŶŐ͘ &ĂƵůƚƌŽƐƐŝŶŐƐĂŶĚ ŽŶĐƌĞƚŝŽŶƐDŽĚĞƌĂƚĞ hƐĞĚĞǀĞůŽƉĞĚďĞƐƚƉƌĂĐƚŝĐĞƐĨŽƌĐŽŶĐƌĞƚŝŽŶĚƌŝůůŝŶŐ͘ ŶƚŝͲŽůůŝƐŝŽŶDŽĚĞƌĂƚĞ&ŽůůŽǁƌĞĂůƚŝŵĞƐƵƌǀĞLJƐǀĞƌLJĐůŽƐĞůLJ͕ƐŚƵƚŝŶŶĞĂƌďLJǁĞůůƐƚŚĂƚǁĞŚĂǀĞĐŽůůŝƐŝŽŶĐŽŶĐĞƌŶƐ ǁŝƚŚ͘hƚŝůŝnjĞƉĞƌŝƐĐŽƉĞƚŽŵĂŝŶƚĂŝŶŐĞŽůŽŐŝĐĂůĐĞƌƚĂŝŶƚLJƚŽƐƚĂLJǁŝƚŚŝŶnjŽŶĞ͘ ĂƐŝŶŐǁĞĂƌDŽĚĞƌĂƚĞ DĂŝŶƚĂŝŶůŽǁĚŽŐůĞŐƐŝŶƚŚĞƐƵƌĨĂĐĞŝŶƚĞƌǀĂůĂŶĚƵƚŝůŝnjĞƐƵƉĞƌƐůŝĚĞƌƐĨŽƌĚƌŝůůŝŶŐ͕ŵŝůůŝŶŐ͕ ĂŶĚůŝŶĞƌƌƵŶŶŝŶŐŽƉĞƌĂƚŝŽŶƐƚŽŵŝŶŝŵŝnjĞĐĂƐŝŶŐǁĞĂƌ͘ŽŶƐŝĚĞƌůŽŐŐŝŶŐĐĂƐŝŶŐƚŚŝĐŬŶĞƐƐ ƚŽĐĂůŝďƌĂƚĞĐĂƐŝŶŐǁĞĂƌŵŽĚĞů͘ 'ĞƚƚŝŶŐ>ŝŶĞƌƚŽŽƚƚŽŵDŽĚĞƌĂƚĞWƌŽƉĞƌůLJĐůĞĂŶŚŽůĞŽŶƚŚĞƚƌŝƉŽƵƚǁŝƚŚƚŚĞ,͕ƉĞƌĨŽƌŵĐůĞĂŶŽƵƚƌƵŶŝĨŶĞĐĞƐƐĂƌLJ͕ ƵƚŝůŝnjĞƐƵƉĞƌƐůŝĚĞƌƐĨŽƌǁĞŝŐŚƚƚƌĂŶƐĨĞƌ͕ŵŽŶŝƚŽƌƚŽƌƋƵĞĂŶĚĚƌĂŐ͘ tŚŝƉƐƚŽĐŬZĞƚƌŝĞǀĂůDŽĚĞƌĂƚĞĚĞĚŝĐĂƚĞĚĐůĞĂŶŽƵƚƌƵŶƉƌŝŽƌƚŽĂƚƚĞŵƉƚŝŶŐƚŽƉƵůůǁŚŝƉƐƚŽĐŬĐĂŶďĞƵƐĞĚƚŽƌĞĚƵĐĞ ƚŚĞƌŝƐŬŽĨĨŝƐŚŝŶŐŽƉĞƌĂƚŝŽŶƐ͘ dŽďĞƉŽƐƚĞĚŝŶZŝŐ&ůŽŽƌŽŐŚŽƵƐĞWƌŝŽƌƚŽ^ƉƵĚ tĞůůWƌŽdžŝŵŝƚLJZŝƐŬƐ͗ ϭ,ŝƐĂŵƵůƚŝͲǁĞůůƉĂĚ͕ĐŽŶƚĂŝŶŝŶŐĂŶŽƌŝŐŝŶĂůƉůĂŶŽĨϯϴǁĞůůƐ ͘dŚĞϭ,E t^WŚĂƐĞϮƉƌŽŐƌĂŵǁŝůůĐŽŶƐŝƐƚ ŽĨϰĚƵĂůůĂƚĞƌĂůǁĞůůƐƚĂƌŐĞƚŝŶŐtĞƐƚ^ĂŬΘƐĂŶĚƐ͘ŝƌĞĐƚŝŽŶĂůĚƌŝůůŝŶŐͬĐŽůůŝƐŝŽŶĂǀŽŝĚĂŶĐĞŝŶĨŽƌŵĂƚŝŽŶ ŝƐƉƌŽǀŝĚĞĚŝŶƚŚĞĨŽůůŽǁŝŶŐĂƚƚĂĐŚŵĞŶƚƐ͘ ƌŝůůŝŶŐƌĞĂZŝƐŬƐ͗ tĞĂŬƐĂŶĚƐƚƌŝŶŐĞƌƐĐŽƵůĚďĞƉƌĞƐĞŶƚŝŶƚŚĞŽǀĞƌďƵƌĚĞŶ͘>DŵĂƚĞƌŝĂůǁŝůůďĞĂǀĂŝůĂďůĞƚŽƐĞĂůŝŶůŽƐƐĞƐŝŶ ƚŚĞŝŶƚĞƌŵĞĚŝĂƚĞƐĞĐƚŝŽŶ͘ &ĂƵůƚƌŽƐƐŝŶŐƐʹ>ŽƐƚĐŝƌĐƵůĂƚŝŽŶ͗^ƚĂŶĚĂƌĚ>DŵĂƚĞƌŝĂůĂŶĚƉ ŽƚĞŶƚŝĂůůLJǁĞůůďŽƌĞƐƚƌĞŶŐƚŚĞŶŝŶŐƉŝůůƐĂƌĞ ĞdžƉĞĐƚĞĚƚŽďĞĞĨĨĞĐƚŝǀĞŝŶĚĞĂůŝŶŐǁŝƚŚůŽƐƚĐŝƌĐƵůĂƚŝŽŶŝĨƌĞƋƵŝƌĞĚ͘ 'ŽŽĚĚƌŝůůŝŶŐƉƌĂĐƚŝĐĞƐǁŝůůďĞƐƚƌĞƐƐĞĚƚŽŵŝŶŝŵŝnjĞƚŚĞƉŽƚĞŶƚŝĂůŽĨƚĂŬŝŶŐƐǁĂďďĞĚŬŝĐŬƐ͘ ϭ,ͲϭϬϳK'ϭϬͲϰϬϭW ϲͬϲͬϮϬϮϰ ϭ,ͲϭϬϳϭϬͲϰϬϭWϭϯͮϭϯ ϭϱ͘ WƌŽƉŽƐĞĚŽŵƉůĞƚŝŽŶ^ĐŚĞŵĂƚŝĐ 40 561 561 761 761 961 961 1201 1201 1501 1501 1801 1801 2001 2001 9001 9001 10001 10001 11001 11001 12001 12001 13001 13001 14001 14001 15001 15001 16001 16001 17001 1H-107 (O31) wp16 Plan Summary 1H-107 (O31) wp16 1H-106 wp16 1H-106L1 wp05 1H-118 1H-401 1H-117 1H-109 1H-112L1 1H-116 1H-114 1H-108 1H-108B 1H-108A 1H-113 1H-112 1H-105 1H-05 1H-502 wp07 1H-120PH1 wp11 1H-119 1H-102L11H-102 1H-102L4 1H-102L3 1H-102L2 1H-107L1 wp07 1H-101L1 1H-101L3 1H-101 1H-101L2 1H-101L4 1H-103 1H-115 1H-104L11H-1041H-104L2 1H-104PB1 1H-111 1H-110 1H-103L31H-103L11H-103L4 1H-103L2 1H-112PH1 H-112PH1 wp07 1H-SOUTH 0 5 Dogleg Severity 0 2500 5000 7500 10000 12500 15000 Measured Depth 13-3/8" Surface Casing 9-5/8" Intermediate Casing 4-1/2" Production Liner 50 50 100 100 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] 1H-106 wp161H-106L1 wp05 1H-401 1H-117 1H-109 1H-1081H-108B1H-108A 1H-102L11H-1021H-102L41H-102L31H-102L2 1H-107L1 wp07 1H-101L11H-101L31H-1011H-101L21H-101L4 1H-103 1H-115 1H-104L11H-1041H-104L21H-104PB1 1H-111 1H-110 1H-103L31H-103L11H-103L41H-103L2 0 6000 True Vertical Depth 0 2500 5000 7500 10000 12500 15000 Vertical Section at 43.00° 13-3/8" Surface Casing 9-5/8" Intermediate Casing 4-1/2" Production Liner 0 50 Centre to Centre Separation 0 4500 9000 13500 18000 22500 27000 Measured Depth DDI 7.071 SURVEY PROGRAM Date: 2017-05-16T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool39.76 1000.00 1H-107 (O31) wp16 (Plan: 1H-107)r.5 SDI_URSA11000.00 1918.16 1H-107 (O31) wp16 (Plan: 1H-107)MWD+IFR2+SAG+MS1918.16 9987.55 1H-107 (O31) wp16 (Plan: 1H-107)MWD+IFR2+SAG+MS 9987.55 16249.88 1H-107 (O31) wp16 (Plan: 1H-107) MWD+IFR2+SAG+MS Surface Location North / 5980444.12 East / 1689607.14 Ground / 54.00 CASING DETAILS TVD MD Name 1863.76 1918.17 13-3/8" Surface Casing 3911.76 9987.55 9-5/8" Intermediate Casing 3998.76 16249.88 4-1/2" Production Liner Mag Model & Date:BGGM2024 01-Jul-24 Magnetic North is 14.04° East of True North (Magnetic Declination) Mag Dip & Field Strength:80.64° 57201.13nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 39.76 0.00 0.00 39.76 0.00 0.00 0.00 0.00 0.00 2 560.00 0.00 0.00 560.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 760.00 3.00 37.00 759.91 4.18 3.15 1.50 37.00 5.21 Start Build 2.00 4 960.00 7.00 37.00 959.11 18.10 13.64 2.00 0.00 22.54 Start DLS 2.50 TFO 10.00 5 1617.99 23.37 44.12 1592.00 144.69 129.43 2.50 10.00 194.09 Start 108.94 hold at 1617.99 MD 6 1726.93 23.37 44.12 1692.00 175.72 159.52 0.00 0.00 237.30 Start Build 3.00 7 1868.16 27.61 44.12 1819.45 219.35 201.82 3.00 0.00 298.06 Start 50.00 hold at 1868.16 MD 8 1918.16 27.61 44.12 1863.76 235.98 217.96 0.00 0.00 321.23 Start 50.00 hold at 1918.16 MD 9 1968.16 27.61 44.12 1908.06 252.62 234.09 0.00 0.00 344.40 Start DLS 3.00 TFO -9.24 10 3798.94 82.25 36.50 2921.46 1373.48 1139.36 3.00 -9.24 1781.54 Start 4700.00 hold at 3798.94 MD 11 8498.94 82.25 36.50 3555.26 5117.09 3909.50 0.00 0.00 6408.68 Start DLS 3.00 TFO 156.12 12 8950.37 69.92 42.29 3663.68 5455.27 4186.48 3.00 156.12 6844.91 Start 378.65 hold at 8950.37 MD 13 9329.02 69.92 42.29 3793.66 5718.34 4425.80 0.00 0.00 7200.52 Start DLS 3.00 TFO 9.47 14 9937.55 87.95 45.25 3909.97 6147.44 4837.55 3.00 9.47 7795.15 Start 50.00 hold at 9937.55 MD 15 9987.55 87.95 45.25 3911.76 6182.62 4873.03 0.00 0.00 7845.08 Start 50.00 hold at 9987.55 MD 16 10037.55 87.95 45.25 3913.55 6217.80 4908.52 0.00 0.00 7895.01 Start DLS 2.00 TFO 78.65 17 10061.24 88.04 45.71 3914.38 6234.40 4925.40 2.00 78.65 7918.67 Start 11.22 hold at 10061.24 MD 18 10072.46 88.04 45.71 3914.76 6242.23 4933.43 0.00 0.00 7929.87 Start DLS 2.50 TFO -62.89 19 10385.31 91.61 38.75 3915.70 6473.68 5143.56 2.50 -62.89 8242.45 Start 81.17 hold at 10385.31 MD 20 10466.48 91.61 38.75 3913.41 6536.96 5194.35 0.00 0.00 8323.37 Start DLS 2.50 TFO 120.38 21 10629.51 89.55 42.27 3911.76 6660.87 5300.23 2.50 120.38 8486.20 Start DLS 2.00 TFO 0.70 22 10687.32 90.71 42.28 3911.63 6703.64 5339.11 2.00 0.70 8543.99 Start 151.84 hold at 10687.32 MD 23 10839.15 90.71 42.28 3909.76 6815.96 5441.26 0.00 0.00 8695.81 Start DLS 2.00 TFO 129.68 24 10958.51 89.18 44.12 3909.88 6902.96 5522.96 2.00 129.68 8815.16 Start 762.14 hold at 10958.51 MD 25 11720.65 89.18 44.12 3920.76 7450.02 6053.50 0.00 0.00 9577.07 Start DLS 2.00 TFO 136.32 26 11759.15 88.62 44.65 3921.50 7477.53 6080.43 2.00 136.32 9615.56 Start 844.38 hold at 11759.15 MD 27 12603.53 88.62 44.65 3941.76 8078.02 6673.70 0.00 0.00 10459.34 Start DLS 2.00 TFO 131.12 28 12661.45 87.86 45.53 3943.53 8118.89 6714.70 2.00 131.12 10517.19 Start 649.74 hold at 12661.45 MD 29 13311.19 87.86 45.53 3967.76 8573.76 7178.01 0.00 0.00 11165.85 Start DLS 2.00 TFO 30.19 30 13392.12 89.26 46.34 3969.79 8630.03 7236.14 2.00 30.19 11246.64 Start 541.54 hold at 13392.12 MD 31 13933.65 89.26 46.34 3976.76 9003.86 7627.89 0.00 0.00 11787.22 Start DLS 2.00 TFO 148.04 32 14005.65 88.04 47.10 3978.45 9053.20 7680.29 2.00 148.04 11859.04 Start 155.21 hold at 14005.65 MD 33 14160.86 88.04 47.10 3983.76 9158.79 7793.93 0.00 0.00 12013.76 Start DLS 2.50 TFO -162.63 34 14373.86 82.96 45.50 4000.46 9305.42 7947.40 2.50 -162.63 12225.67 Start 41.02 hold at 14373.86 MD 35 14414.88 82.96 45.50 4005.49 9333.95 7976.44 0.00 0.00 12266.34 Start DLS 2.50 TFO -2.14 36 14686.66 89.75 45.25 4022.76 9524.37 8169.37 2.50 -2.14 12537.18 Start DLS 2.50 TFO -77.48 37 15016.26 91.53 37.20 4019.06 9772.03 8386.40 2.50 -77.48 12866.32 Start 86.16 hold at 15016.26 MD 38 15102.43 91.53 37.20 4016.76 9840.64 8438.48 0.00 0.00 12952.02 Start DLS 2.00 TFO 56.04 39 15176.33 92.36 38.43 4014.25 9898.98 8483.76 2.00 56.04 13025.57 Start 206.40 hold at 15176.33 MD 40 15382.72 92.36 38.43 4005.76 10060.53 8611.94 0.00 0.00 13231.13 Start DLS 2.00 TFO 139.75 41 15489.00 90.74 39.80 4002.89 10142.95 8678.97 2.00 139.75 13337.13 Start 477.99 hold at 15489.00 MD 42 15967.00 90.74 39.80 3996.76 10510.13 8984.94 0.00 0.00 13814.34 Start DLS 2.00 TFO -171.66 43 16032.10 89.45 39.62 3996.66 10560.21 9026.54 2.00 -171.66 13879.33 Start 217.78 hold at 16032.10 MD 44 16249.88 89.45 39.62 3998.76 10727.97 9165.39 0.00 0.00 14096.72 TD at 16249.88 FORMATION TOP DETAILS TVDPath Formation 1498.76 T-5 1638.76 Base Permafrost 1898.76 T-3 2112.76 K-15 3053.76 Ugnu C 3342.76 Ugnu B 3473.76 Ugnu A 3648.76 Nb 3859.76 WSAK D 3892.76 WSAK C 3910.76 WSAK B Plan: 54 PL +39.76 DF @ 93.76usft (Doyon 25) Project: Kuparuk River Unit_1Site: Kuparuk 1H PadWell: Plan: 1H-107 (O31)Wellbore: Plan: 1H-107Design: 1H-107 (O31) wp16045009000South(-)/North(+)0 4500 9000 13500 18000West(-)/East(+)1H-107 Int Casing1H-107 T09 Rev3.01H-107 T07 Rev3.01H-107 TD 1320ft1H-107 T04 Rev3.01H-107 TD Rev2.01H-107 T10 Rev2.01H-107 T01 Rev3.01H-107 T02 Rev2.01H-107 T06 Rev3.01H-107 T08 Rev3.01H-107 Extra T01 Rev1.01H-107 T0 Heel Rev4.01H-107 T05 Rev3.01H-107 T03 Rev2.01H-107 T0 1320ft1H-106 wp161H-106L1 wp051H-1181H-4011H-1171H-1091H-112PH11H -112L11 H -1 1 6 1H-1141H-1081H-108B1H -10 8A 1 H -1 1 31H-1121H -1051 H -0 51H-502 wp071H-120L1 wp151H-120PH1 wp111H-120 wp17 (OHST)1H-1191H-102L11H-1021H-102L41H-102L31H-102L21H-107L1 wp071H-101L11H-101L31H-1011H-101L21H-101L41H-1031H-1151H-104L11H-1041H-104L21H-104PB11 H -111 1H-1101H-103L31H-103L11H-103L41H-103L21H-112PH11H -112L11H -112H-112PH1 wp071H -112P H 11H-SOUTH13-3/8" Surface Casing9-5/8" Intermediate Casing4-1/2" Production Liner500100015002000250030003500400039981H-107 (O31) wp16Plan View with offset wells Project: Kuparuk River Unit_1Site: Kuparuk 1H PadWell: Plan: 1H-107 (O31)Wellbore: Plan: 1H-107Design: 1H-107 (O31) wp16045009000South(-)/North(+)0 4500 9000 13500 18000West(-)/East(+)1H-107 Int Casing1H-107 T09 Rev3.01H-107 T07 Rev3.01H-107 TD 1320ft1H-107 T04 Rev3.01H-107 TD Rev2.01H-107 T10 Rev2.01H-107 T01 Rev3.01H-107 T02 Rev2.01H-107 T06 Rev3.01H-107 T08 Rev3.01H-107 Extra T01 Rev1.01H-107 T0 Heel Rev4.01H-107 T05 Rev3.01H-107 T03 Rev2.01H-107 T0 1320ft1H-107L1 wp0713-3/8" Surface Casing9-5/8" Intermediate Casing4-1/2" Production Liner500100015002000250030003500400039981H-107 (O31) wp16Plan View 019003800True Vertical Depth (950 usft/in)0 4000 8000 12000 16000Vertical Section at 43.00° (2000 usft/in)Plan: 1H-107 (O31)/1H-107L1 wp0713-3/8" Surface Casing9-5/8" Intermediate Casing4-1/2" Production Liner100020003000400050006000700080009000100001100012000130001400015000 16000Plan: 1H-107 (O31)/1H-107 (O31) wp16Start Build 1.50Start Build 2.00Start DLS 2.50 TFO 10.00Start 108.94 hold at 1617.99 MDStart Build 3.00Start 50.00 hold at 1867.29 MDStart 50.00 hold at 1917.29 MDStart DLS 3.00 TFO -9.24Start 4700.00 hold at 3798.93 MDStart DLS 3.00 TFO 155.93Start 384.68 hold at 8947.38 MDStart DLS 3.00 TFO 9.52Start 50.00 hold at 9937.32 MDStart 50.00 hold at 9987.32 MDStart DLS 2.00 TFO 78.65Start 11.22 hold at 10061.01 MDStart DLS 2.50 TFO -62.89Start 81.17 hold at 10385.08 MDStart DLS 2.50 TFO 120.38Start DLS 2.00 TFO 0.70Start 151.84 hold at 10687.09 MDStart DLS 2.00 TFO 129.68Start 762.14 hold at 10958.28 MDStart DLS 2.00 TFO 136.32Start 844.38 hold at 11758.93 MDStart DLS 2.00 TFO 131.12Start 649.74 hold at 12661.22 MDStart DLS 2.00 TFO 30.19Start 541.54 hold at 13391.89 MDStart DLS 2.00 TFO 148.04Start 155.21 hold at 14005.42 MDStart DLS 2.50 TFO -162.63Start 41.02 hold at 14373.63 MDStart DLS 2.50 TFO -2.14Start DLS 2.50 TFO -77.48Start 86.16 hold at 15016.04 MDStart DLS 2.00 TFO 56.04Start 206.40 hold at 15176.10 MDStart DLS 2.00 TFO 139.75Start 477.99 hold at 15488.78 MDStart DLS 2.00 TFO -171.66Start 217.78 hold at 16031.88 MDTD at 16249.65Section View Project: Kuparuk River Unit_1Site: Kuparuk 1H PadWell: Plan: 1H-107 (O31)Wellbore: Plan: 1H-107Design: 1H-107 (O31) wp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rom:Kelley, Trevor To:Loepp, Victoria T (OGC); Davies, Stephen F (OGC) Cc:Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL]RE: 1H-107 (PTD 224-092), 1H-107L1 (PTD 224-093) - Updates to PTD Applications Date:Monday, July 29, 2024 1:10:07 PM Victoria, We are not planning to run the LWD Sonic tool as this well is a producer that will not be hydraulically fractured. Our plan is to use volumetric calculation as our method for determining top of cement. If severe losses or another issue are seen that would cause uncertainty in the top of cement, then a log would be performed in order to determine top of cement and cement at the L1 window. Please let me know if you have any further questions. Thank you, Trevor Kelley | Drilling Engineer | ConocoPhillips Alaska C: 281-513-6789 | 700 G Street Anchorage, AK 99501 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, July 29, 2024 11:40 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Kelley, Trevor <Trevor.Kelley@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL]RE: 1H-107 (PTD 224-092), 1H-107L1 (PTD 224-093) - Updates to PTD Applications Trevor, Please explain why you are not running the LWD Sonic tool to determine the intermediate TOC and quality? The Sonic is required to verify the amount of cement above the Ugnu C. In addition, cement presence at the 1H-107L1 window is required. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Tuesday, July 16, 2024 8:32 AM To: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL]RE: 1H-107 (PTD 224-092), 1H-107L1 (PTD 224-093) - Updates to PTD Applications Trevor, I made your updates (below) to the PTD applications. Regards, Steve Davies AOGCC From: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Sent: Monday, July 15, 2024 4:12 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]RE: 1H-107, 1H-107L1 PTD Applications Steve, I have noticed two updates that need to be made to the 1H-107 and 1H-107L1 permit applications Grade on 4-1/2” casing should be 13CR80 (instead of L80) for both the 1H-107 and 1H- 107L1 On the 1H-107 application under Section 3. Drilling Program (page 5), step 21 should have Sonic removed from the LWD program. We are not planning to run a Sonic log on this well Thank you, Trevor Kelley | Drilling Engineer | ConocoPhillips Alaska C: 281-513-6789 | 700 G Street Anchorage, AK 99501 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, July 15, 2024 8:16 AM To: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Subject: RE: [EXTERNAL]RE: 1H-107, 1H-107L1 PTD Applications Kelley, You don't often get email from trevor.kelley@conocophillips.com. Learn why this is important Thank you for your help with this. Thanks Again and Be Well, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Sent: Monday, July 15, 2024 8:04 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]RE: 1H-107, 1H-107L1 PTD Applications Steve, Sorry about that. Attached is the as built file with the coordinates on pages 2 and 3. Thank you, Trevor Kelley | Drilling Engineer | ConocoPhillips Alaska C: 281-513-6789 | 700 G Street Anchorage, AK 99501 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Friday, July 12, 2024 1:49 PM To: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Subject: [EXTERNAL]RE: 1H-107, 1H-107L1 PTD Applications CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Trevor, I’m reviewing the 1H-107 Permit to Drill application. I notice that the Pad Layout plat within CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Some people who received this message don't often get email from trevor.kelley@conocophillips.com. Learn why this is important the application is not accompanied by a coordinate table so that I can cross-check the surface coordinates for this well. Could CPAI please provide a copy of this table? Thanks and Be Well, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Sent: Wednesday, July 3, 2024 8:10 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: 1H-107, 1H-107L1 PTD Applications Good Morning, Please see the attached 10-401 submissions for the 1H-107 and 1H-107L1. I have also attached the directional plans in .txt format for your reference. Please let me know if you need anything else. Thanks, Trevor Kelley | Drilling Engineer | ConocoPhillips Alaska C: 281-513-6789 | 700 G Street Anchorage, AK 99501 From:Davies, Stephen F (OGC) To:Kelley, Trevor Cc:Loepp, Victoria T (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL]RE: 1H-107 (PTD 224-092), 1H-107L1 (PTD 224-093) - Updates to PTD Applications Date:Tuesday, July 16, 2024 8:31:00 AM Trevor, I made your updates (below) to the PTD applications. Regards, Steve Davies AOGCC From: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Sent: Monday, July 15, 2024 4:12 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]RE: 1H-107, 1H-107L1 PTD Applications Steve, I have noticed two updates that need to be made to the 1H-107 and 1H-107L1 permit applications Grade on 4-1/2” casing should be 13CR80 (instead of L80) for both the 1H-107 and 1H- 107L1 On the 1H-107 application under Section 3. Drilling Program (page 5), step 21 should have Sonic removed from the LWD program. We are not planning to run a Sonic log on this well Thank you, Trevor Kelley | Drilling Engineer | ConocoPhillips Alaska C: 281-513-6789 | 700 G Street Anchorage, AK 99501 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, July 15, 2024 8:16 AM To: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Subject: RE: [EXTERNAL]RE: 1H-107, 1H-107L1 PTD Applications Kelley, Thank you for your help with this. Thanks Again and Be Well, You don't often get email from trevor.kelley@conocophillips.com. Learn why this is important Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Sent: Monday, July 15, 2024 8:04 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]RE: 1H-107, 1H-107L1 PTD Applications Steve, Sorry about that. Attached is the as built file with the coordinates on pages 2 and 3. Thank you, Trevor Kelley | Drilling Engineer | ConocoPhillips Alaska C: 281-513-6789 | 700 G Street Anchorage, AK 99501 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Friday, July 12, 2024 1:49 PM To: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Subject: [EXTERNAL]RE: 1H-107, 1H-107L1 PTD Applications CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Trevor, I’m reviewing the 1H-107 Permit to Drill application. I notice that the Pad Layout plat within the application is not accompanied by a coordinate table so that I can cross-check the surface coordinates for this well. Could CPAI please provide a copy of this table? CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Some people who received this message don't often get email from trevor.kelley@conocophillips.com. Learn why this is important Thanks and Be Well, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Sent: Wednesday, July 3, 2024 8:10 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: 1H-107, 1H-107L1 PTD Applications Good Morning, Please see the attached 10-401 submissions for the 1H-107 and 1H-107L1. I have also attached the directional plans in .txt format for your reference. Please let me know if you need anything else. Thanks, Trevor Kelley | Drilling Engineer | ConocoPhillips Alaska C: 281-513-6789 | 700 G Street Anchorage, AK 99501 From:Kelley, Trevor To:Davies, Stephen F (OGC) Subject:RE: [EXTERNAL]RE: 1H-107, 1H-107L1 PTD Applications Date:Monday, July 15, 2024 8:05:29 AM Attachments:1H As-Built 2017.pdf You don't often get email from trevor.kelley@conocophillips.com. Learn why this is important Steve, Sorry about that. Attached is the as built file with the coordinates on pages 2 and 3. Thank you, Trevor Kelley | Drilling Engineer | ConocoPhillips Alaska C: 281-513-6789 | 700 G Street Anchorage, AK 99501 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Friday, July 12, 2024 1:49 PM To: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Subject: [EXTERNAL]RE: 1H-107, 1H-107L1 PTD Applications CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Trevor, I’m reviewing the 1H-107 Permit to Drill application. I notice that the Pad Layout plat within the application is not accompanied by a coordinate table so that I can cross-check the surface coordinates for this well. Could CPAI please provide a copy of this table? Thanks and Be Well, Steve Davies Senior Petroleum Geologist AOGCC 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 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Some people who received this message don't often get email from trevor.kelley@conocophillips.com. Learn why this is important AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Kelley, Trevor <Trevor.Kelley@conocophillips.com> Sent: Wednesday, July 3, 2024 8:10 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: 1H-107, 1H-107L1 PTD Applications Good Morning, Please see the attached 10-401 submissions for the 1H-107 and 1H-107L1. I have also attached the directional plans in .txt format for your reference. Please let me know if you need anything else. Thanks, Trevor Kelley | Drilling Engineer | ConocoPhillips Alaska C: 281-513-6789 | 700 G Street Anchorage, AK 99501 Revised 7/2022 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 Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The 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-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot 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 this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a 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 the Operator 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 all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. KUPARUK RIVER WEST SAK OIL 224-092 KRU 1H-107 WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV U WSAK 1H-107Initial Class/TypeDEV / PENDGeoArea890Unit11160On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2240920KUPARUK RIVER, WEST SAK OIL - 490150NA1Permit fee attachedYesSurface Location lies within ADL0025639; Top Productive Interval lies in ADL0025636; TD lies in ADL0025637.2Lease number appropriateYes3Unique well name and numberYesKUPARUK RIVER, WEST SAK OIL - 490150 - governed by CO 406C4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes80' conductor18Conductor string providedYesSC set at 1918' MD19Surface casing protects all known USDWsYes202% access cement planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoProductive interval will be completed with open hole screens22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedYes27If diverter required, does it meet regulationsYesMax reservoir pressure is 1913 psig(9.2 ppg EMW); will drill w/ 8.8-9.5 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYes MPSP is 1513 psig; will test BOPE to 5000 initially & 3500 psig subsequently; 21 day BOPE testing frequency30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYes33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)NoH2S Measures Required: 1H-Pad Wsak wells measured 103 to 160 pm H2S in July 2023.35Permit can be issued w/o hydrogen sulfide measuresYesExpected pressure range is 0.442 to 0.479 psi/ft (8.5 to 9.2 ppg EMW). Operator's planned mud program36Data presented on potential overpressure zonesNAappears sufficient to control anticipated pressures and maintain wellbore stability.37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate7/12/2024ApprVTLDate7/30/2024ApprSFDDate7/12/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateDrilling Hazards Summary notes moderate potential of encountering the following risks: Gas Hydrates, Hole Swabbing, Lost Circulation, Differential Sticking, and Faulting. Mitigation measures are discussed on p. 11 and 12.*&:JLC 7/31/2024
