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Home My WebLink About225-025MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3S-721 KUPARUK RIV UNIT 3S-721 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 3S-721 50-103-20911-00-00 225-025-0 W SPT 3953 2250250 1500 80 80 80 80 617 665 643 639 INITAL P Josh Hunt 11/15/2025 This is the initial MIT-IA after stable flow has been achieved. The well is taking fluid very well resulting in a very low tubing pressure. Good test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3S-721 Inspection Date: Tubing OA Packer Depth 875 2010 1970 1965IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH251116132125 BBL Pumped:1.5 BBL Returned:1.5 Friday, January 16, 2026 Page 1 of 1            Originated: Delivered to:4-Dec-25Alaska Oil & Gas Conservation Commiss04Dec25-NR !"#$$%$ !&$$'($) *%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED2P-447 50-103-20468-00-00 203-154 Kuparuk River WL IBC-CBL FINAL FIELD18-Nov-253S-08&50-103-20450-03-00 207-163 Kuparuk River WL Cutter FINAL FIELD 21-Nov-253S-09 50-103-20432-00-00 202-205 Kuparuk River WL Cutter FINAL FIELD 22-Nov-253S-705 50-103-20915-00-00 225-047 Kuparuk River WL TTiX-iPROF-SCMT FINAL FIELD 28-Nov-253S-721 50-103-20911-00-00 225-025 Kuparuk River WL TTiX-iPROF FINAL FIELD 1-Dec-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1Please return via courier or sign/scan and email a copy to Schlumberger."2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8" ! - +"8#!(3 . 8)"3 8#!9 3 : 8" +868 8 "8#!;" " 3 - 3" 3""+ 3 + <+3!% T41188T11189T41190T41191T411923S-72150-103-20911-00-00225-025Kuparuk RiverWLTTiX-iPROFFINAL FIELD1-Dec-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.12.05 11:22:02 -09'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? KRU 3S-721 Yes No 9. Property Designation (Lease Number): 10. Field: Coyote Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 20671 4203.00 20664 4203.00 1972 None None Casing Collapse Structural Conductor Surface 2470 Intermediate 4790 Intermediate 7850 Liner 9210 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:Rodrigo Ruysschaert Rodrigo Ruysschaert Contact Email:Rodrigo.Ruysschaert@cop.com Contact Phone: 907-621-0671 Authorized Title:Completions Engineer 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 8630 3842 4-1/2"20664 11590 852 11185 4203 7-5/8"8670 6890 7-5/8"9522 108604006 PRESENT WELL CONDITION SUMMARY Length Size TVD Burst MPSP (psi):Plugs (MD): 20"132 10-3/4"3055 5210 Tubing MD (ft): 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: 9483 Aug 30 2025 Halliburton TNT Prod Packer Baker SLZXP, No SSSV Perforation Depth TVD (ft): L-80 Perforation Depth MD (ft): AOGCC USE ONLY 4-1/2" Tubing Grade: Aug 27 2025 Subsequent Form Required: Suspension Expiration Date: TNT packer: 9332 ft MD/3953 ft TVD SLZXP packer: 9479 ft MD/3978 ft TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL380107 / ADL025544 / ADL025551 225-025 P.O. Box 100360, Anchorage, Alaska 99510-0360 50-103-20911-00-00 ConocoPhillips Alaska Inc. Proposed Pools: Kuparuk Field Will perfs require a spacing exception due to property boundaries? Current Pools: 80 3014 MD 132 2514 m n P _ 2 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:51 am, Aug 28, 2025 325-523 DSR-8/28/25 Change to Approved Sundry 325-334. CDW. A.Dewhurst 28AUG25 10-404 CDW 08/28/2025 VTL 8/28/2025JLC 8/29/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.29 08:14:27 -08'00'08/29/25 RBDMS JSB 082925 Hydraulic Fracturing Fluid Product Component Information Disclosure 2025-05-31 Alaska HARRISON BAY 50-103-20911-00-00 CONOCOPHILLIPS 3S 721 -150.19794822 70.39407078 NAD83 none Oil 4205 1607318.6 Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Ingredient Mass lbs Comments Company First Name Last Name Email Phone Produced Water (Density 8.5)Operator Base Fluid Density = 8.50 SEAWATER (SG 8.52)Operator Base Fluid Density = 8.52 BA-20 BUFFERING AGENT Halliburton Buffer BC-140 X2 Halliburton Initiator BE-6(TM) Bactericide Halliburton Microbiocide CAT-3 ACTIVATOR Halliburton Activator Legend LD-6450 MultiChem Completion/Stimulatio n LoSurf-300D Halliburton Non-ionic Surfactant MO-67 Halliburton pH Control OPTIFLO-HTE Halliburton Breaker OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker WG-36 GELLING AGENT Halliburton Gelling Agent Ceramic Proppant - Wanli Wanli Proppant Sand-Common White-100 Mesh, SSA-2 Halliburton Proppant Calcium Chloride Customer Salt Solution CarboLite 16/20 Carbo Ceramics Proppant Flow Insurance Copper Patina Energy Tracer Fresh Water Operator Base Fluid OPT 2002-2054 ResMetrics Tracer WPT 1001-1052 ResMetrics Tracer Ingredients Water 7732-18-5 95.00%51.42517%13690095 Ceramic Materials and Wares, Chemicals 66402-68-4 100.00%22.53827%6000000 Corundum 1302-74-5 60.00%13.52296%3600000 Mullite 1302-93-8 40.00%9.01531%2400000 Sodium chloride 7647-14-5 5.00%2.70659%720532 Water 7732-18-5 100.00%0.23117%61542 Crystalline silica, quartz 14808-60-7 100.00%0.22721%60487 Guar gum 9000-30-0 100.00%0.17053%45397 Calcium chloride, dihyrate 10035-04-8 60.00%0.04054%10793 Calcium Chloride 10043-52-4 100.00%0.03756%10000 EDTA/Copper chelate Proprietary 30.00%0.03160%8412 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871- 6226 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Ethanol 64-17-5 60.00%0.02879%7666 Monoethanolamine borate 26038-87-9 100.00%0.02591%6899 Water 7732-18-5 100.00%0.01596%4250 Heavy aromatic petroleum naphtha 64742-94-5 30.00%0.01440%3833 Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.01440%3833 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Ammonium persulfate 7727-54-0 100.00%0.01263%3362 Sodium hydroxide 1310-73-2 30.00%0.00900%2396 Ethylene glycol 107-21-1 30.00%0.00777%2070 Ammonium chloride 12125-02-9 5.00%0.00527%1402 Oxyalkylated phenolic resin Proprietary 10.00%0.00480%1278 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Oxylated phenolic resin Proprietary 30.00%0.00379%1009 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Copolymer of acrylamide and sodium acrylate 25085-02-3 5.00%0.00338%900 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00%0.00240%639 Naphthalene 91-20-3 5.00%0.00240%639 Walnut hulls NA 100.00%0.00188%500 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Flow Insurance Copper Proprietary 100.00%0.00152%405 Patina Energy Product Stewardship test@patinae nergy.com 6692416025 Ammonia 7664-41-7 1.00%0.00105%281 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00095%252 Polyamine Proprietary 30.00%0.00056%150 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Glycol Ether Proprietary 85.00%0.00051%136 ResMetrics Product Stewardship info@resmetri cs.com 8325921900 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00048%128 Ammonium acetate 631-61-8 100.00%0.00035%92 Sodium chloride 7647-14-5 1.00%0.00030%80 Confidential Proprietary 20.00%0.00018%49 ResMetrics Product Stewardship info@resmetri cs.com 8325921900 C.I. pigment Orange 5 3468-63-1 1.00%0.00013%34 Ethylene Glycol 107-21-1 20.00%0.00013%34 Acetic acid 64-19-7 30.00%0.00010%28 Hemicellulase 9025-56-3 5.00%0.00009%25 Polymer Proprietary 0.10%0.00007%18 MultiChem Ana Djuric Ana.Djuric@ Halliburton.co m 281-871- 5747 2,7-Naphthalenedisulfonic acid, 3- hydroxy-4-[(4-sulfor-1- naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00003%7 C.I. Pigment Red 5 6410-41-9 1.00%0.00002%5 Cured acrylic resin Proprietary 1.00%0.00002%5 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 * Total Water Volume sources may include fresh water, produced water, and/or recycled water _ ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.5 All component information listed was obtained from the supplier’s Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration’s (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D. Production Type: True Vertical Depth (TVD): Total Water Volume (gal)*: MSDS and Non-MSDS Ingredients are listed below the green line Well Name and Number: Longitude: Latitude: Long/Lat Projection: Indian/Federal: Fracture Date State: County: API Number: Operator Name: CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39407078LEASE3S-721SALES ORDERBHST (°F)LONG-150.1979482FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)1-1 Shut-In Shut-In2:06:09 1-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:06:09 1-3 Shut-In Shut-In2:01:23 1-4 27# Linear Arsenal Sleeve Shift 5 1,260 30 30 0:06:00 2:01:23 1.00 2.00 1.00 27.00 2.000.151-5 27# Linear DFIT 10 1,680 40 40 0:04:00 1:55:23 1.00 2.00 1.00 27.00 2.000.151-6 Shut-In Shut-In1:51:23 1-7 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 1:51:23 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-8 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-9 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-12 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-16 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.151-17 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.152-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 1:50:33 1.0000 2.00 1.00 27.00 2.000.152-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 1:48:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.152-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.00 0.153-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:09:42 1.00 2.00 1.00 27.00 2.000.153-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:07:12 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:57:12 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:37:38 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:30:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:25:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 1:16:19 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 1:06:55 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:51:41 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:37:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:27:29 0.45 1.00 0.50 2.00 1.00 27.00 2.000.153-12 27# Linear Flush 20 12,511 298 298 0:14:54 0:20:54 1.00 2.00 1.00 27.00 2.000.153-13 Freeze Protect Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 3-14 Shut-In Shut-InInterval 1Coyote@ 20530.63 - 20534.63 ft - °FInterval 2Coyote@ 20028.89 - 20032.89 ft - °FInterval 3Coyote@ 19572.34 - 19576.34 ft - °FLiquid AdditivesDry Additives50-103-20911Conoco Phillips - 3S-723Planned Design1 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39407078LEASE3S-721SALES ORDERBHST (°F)LONG-150.1979482FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-209114-1 Shut-In Shut-In1:58:09 4-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:58:09 4-3 Shut-In Shut-In1:53:23 4-4 27# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 1:53:23 1.00 2.00 1.00 27.00 2.000.154-5 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 1:51:23 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-6 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-7 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-12 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.154-15 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.155-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 1:50:33 1.00 2.00 1.00 27.00 2.000.155-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 1:48:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.155-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.156-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 1:50:33 1.00 2.00 1.00 27.00 2.000.156-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 1:48:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.156-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.157-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:08:19 1.00 2.00 1.00 27.00 2.000.157-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:05:49 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:55:49 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:36:15 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.0000 20 3,850 92 100 7,700 0:05:00 1:28:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:23:57 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 1:14:56 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 1:05:32 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:50:18 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:36:10 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:26:06 0.45 1.00 0.50 2.00 1.00 27.00 2.000.157-12 27# Linear Flush 20 11,344 270 270 0:13:30 0:19:30 1.00 2.00 1.00 27.00 2.000.157-13 Freeze Protect Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 7-14 Shut-In Shut-InInterval 4Coyote@ 19115.43 - 19119.43 ft - °FInterval 5Coyote@ 18659.2 - 18663.2 ft - °FInterval 6Coyote@ 18202.02 - 18206.02 ft - °FInterval 7Coyote@ 17747.72 - 17751.72 ft - °FConoco Phillips - 3S-723Planned Design2 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39407078LEASE3S-721SALES ORDERBHST (°F)LONG-150.1979482FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-209118-1 Shut-In Shut-In2:20:42 8-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:20:42 8-3 Shut-In Shut-In2:15:56 8-4 27# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 2:15:56 1.00 2.00 1.00 27.00 2.000.158-5 27# Linear Displace Dart to Seat 15 11,052 263 263 0:17:33 2:13:56 1.00 2.00 1.00 27.00 2.000.158-6 27# Linear DFIT 10 2,100 50 50 0:05:00 1:56:23 1.00 2.00 1.00 27.00 2.000.158-7 Shut-In Shut-In1:51:23 8-8 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 1:51:23 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-9 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-10 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-12 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-16 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-17 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.158-18 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.159-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 1:50:33 1.00 2.00 1.00 27.00 2.000.159-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 1:48:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.159-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1510-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 1:50:33 1.00 2.00 1.00 27.00 2.000.1510-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 1:48:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1510-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1511-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:06:53 1.00 2.00 1.00 27.00 2.000.1511-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:04:23 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:54:23 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:34:50 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:27:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:22:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 1:13:31 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 1:04:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:48:53 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:34:45 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:24:40 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1511-12 27# Linear Flush 20 10,150 242 242 0:12:05 0:18:05 1.00 2.00 1.00 27.00 2.000.1511-13 Freeze Protect Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 11-14 Shut-In Shut-InInterval 9Coyote@ 16833.71 - 16837.71 ft - °FInterval 10Coyote@ 16336.24 - 16340.24 ft - °FInterval 11Coyote@ 15878.93 - 15882.93 ft - °FInterval 8Coyote@ 17290.69 - 17294.69 ft - °FConoco Phillips - 3S-723Planned Design3 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39407078LEASE3S-721SALES ORDERBHST (°F)LONG-150.1979482FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-2091112-1 Shut-In Shut-In1:58:09 12-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 1:58:09 12-3 Shut-In Shut-In1:53:23 12-4 27# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 1:53:23 1.00 2.00 1.00 27.00 2.000.1512-5 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 1:51:23 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-6 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-7 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-12 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1512-15 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1513-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 1:50:33 1.00 2.00 1.00 27.00 2.000.1513-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 1:48:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1513-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1514-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 1:50:33 1.00 2.00 1.00 27.00 2.000.1514-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 1:48:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1514-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1515-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 2:05:20 1.00 2.00 1.00 27.00 2.000.1515-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 2:02:50 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:52:50 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:33:17 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:25:59 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:20:58 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 1:11:58 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 1:02:34 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:47:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:33:12 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:23:07 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1515-12 27# Linear Flush 20 8,849 211 211 0:10:32 0:16:32 1.00 2.00 1.00 27.00 2.000.1515-13 Freeze Protect Freeze Protect 5 1,260 30 30 0:06:00 0:06:00 15-14 Shut-In Shut-InInterval 12Coyote@ 15380.54 - 15384.54 ft - °FInterval 13Coyote@ 14881.74 - 14885.74 ft - °FInterval 14Coyote@ 14341.79 - 14345.79 ft - °FInterval 15Coyote@ 13843.98 - 13847.98 ft - °FConoco Phillips - 3S-723Planned Design4 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39407078LEASE3S-721SALES ORDERBHST (°F)LONG-150.1979482FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-2091116-1 Shut-In Shut-In2:16:42 16-2 Freeze Protect Prime Up Pressure Test 5 1,000 24 24 0:04:46 2:16:42 16-3 Shut-In Shut-In2:11:56 16-4 27# Linear Spacer and Dart Drop 15 1,260 30 30 0:02:00 2:11:56 1.00 2.00 1.00 27.00 2.000.1516-5 27# Linear Displace Dart to Seat 15 8,531 203 203 0:13:32 2:09:56 1.00 2.00 1.00 27.00 2.000.1516-6 27# Linear DFIT 10 2,100 50 50 0:05:00 1:56:23 1.00 2.00 1.00 27.00 2.000.1516-7 Shut-In Shut-In1:51:23 16-8 27# Delta Frac Establish Stable Fluid 15 8,400 200 200 0:13:20 1:51:23 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-9 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-10 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-12 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-13 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-14 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-15 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-16 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-17 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1516-18 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1517-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 1:50:33 1.00 2.00 1.00 27.00 2.000.1517-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 1:48:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1517-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1518-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 1:50:33 1.00 2.00 1.00 27.00 2.000.1518-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1518-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1519-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 1:50:33 1.00 2.00 1.00 27.00 2.000.1519-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 1:48:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1519-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.000.1520-1 27# Linear Pre-Pad 20 2,100 50 50 0:02:30 1:50:33 1.00 2.00 1.00 27.00 2.000.1520-2 27# Delta Frac Establish Stable Fluid 20 8,400 200 200 0:10:00 1:48:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-3 27# Delta Frac Pad 20 16,430 391 391 0:19:34 1:38:03 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-4 27# Delta Frac Conditioning Pad 100M 0.50 20 6,000 143 146 3,000 0:07:18 1:18:30 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-5 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 2.00 20 3,850 92 100 7,700 0:05:00 1:11:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-6 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 4.00 20 6,400 152 180 25,600 0:09:01 1:06:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-7 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 6.00 20 6,200 148 187 37,200 0:09:24 0:57:11 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-8 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 7.00 20 9,700 231 303 67,900 0:15:14 0:47:47 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-9 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 8.00 20 8,700 207 281 69,600 0:14:08 0:32:33 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-10 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 9.00 20 6,000 143 200 54,000 0:10:04 0:18:25 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-11 27# Delta Frac Proppant Laden Fluid Wanli 16/20 Ceramic 10.00 20 3,800 90 131 38,000 0:06:35 0:08:20 0.45 1.00 0.50 2.00 1.00 27.00 2.000.1520-12 27# Linear Spacer and Dart Drop 20 1,470 35 35 0:01:45 0:01:45 1.00 2.00 1.00 27.00 2.00 0.1521-1 27# Linear Displace Dart to Seat 20 6,201 148 148 0:07:23 0:08:53 1.00 2.00 1.00 27.00 2.000.1521-2 27# Linear Load Well 20 1,260 30 30 0:01:30 0:01:30 1.00 2.00 1.00 27.00 2.000.1521-3 Shut-In Shut-In1,656,738 39,446 45,883 6,060,00015:35:04 Interval 16Coyote@ 13346.39 - 13350.39 ft - °FInterval 17Coyote@ 12850.11 - 12854.11 ft - °FInterval 18Coyote@ 12351.65 - 12355.65 ft - °FInterval 19Coyote@ 11853.01 - 11857.01 ft - °FInterval 20Coyote@ 11354.54 - 11358.54 ft - °FInterval 21Coyote@ 9701.83 - Conoco Phillips - 3S-723Planned Design5 CUSTOMERConoco Phillips FALSEAPIBFD (lb/gal)8.54LAT 70.39407078LEASE3S-721SALES ORDERBHST (°F)LONG-150.1979482FORMATIONCoyoteDATE Max Pressure (psi)Prop Slurry Design Clean Design Clean Design Slurry Design Prop Stage Interval BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-IIBE-6TreatmentStage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time TimeCrosslinker Surfactant Buffer Catalyst Clay ControlInterval Number Description Description Description(ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt)Liquid AdditivesDry Additives50-103-20911Design Total (gal)Design Total (lbs)BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-II BE-61,509,6006,000,000(gal) (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs)137,09860,000Initial Design Material Volume 679.3 1,646.7 754.8 3,293.4 1,646.7 44,460.9 3,293.4 247.0-10,040- 0.2761 Whole Units to be ordered--BC-140X2 Losurf-300D MO-67 CAT-3 LD-6450 WG-36 OPTIFLO-II BE-6-(gpm) (gpm) (gpm) (gpm) (gpm) ppm ppm ppm-Max Additive Rate 0.4 0.8 0.4 1.7 0.8 22.7 1.7 0.1-Min Additive RateProppant TypeWanli 16/20 Ceramic100M---Fluid Type27# Delta Frac27# LinearSeawaterFreeze Protect----Conoco Phillips - 3S-723Planned Design6 T R A N S M I T T A LL FROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7 th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska RE: 3S-721 Permit: 225-025 DATE:7/28/2025 Transmitted: 3S-721 Via SFTP ____ Halliburton Mudlog Data Package 225-025 T40720 Transmittal instructions: please promptly sign, scan, and e-mail to AKGGREDTSupport@ConocoPhillips.onmicrosoft.COM CC: 3S-721 - e-transmittal well folder Receipt: Date: Alaska/IT-Data Services |ConocoPhillips Alaska | Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 15:02:52 -08'00' WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDCOLOR PRINTS E-Delivery3S-721 50-103-20911-00-00 225-025 KUPARUK RIVER MWD/LWD/DD TOP OF CEMENT FINAL FIELD 7-May-25 13T-613 50-103-20914-00-00 225-036 KUPARUK RIVER MWD/LWD/DD TOP OF CEMENT FINAL FIELD 23-May-25 13T-605 50-103-20917-00-00 225-051 KUPARUK RIVER MWD/LWD/DD TOP OF CEMENT FINAL FIELD 21-Jun-25 13S-719 50-103-20919-00-00 225-058 KUPARUK RIVER MWD/LWD/DD TOP OF CEMENT FINAL FIELD 15-Jul-25 1Transmittal Receipt________________________________ X____________________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.aurana@slb.comSLB Auditor - A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point.# Schlumberger-PrivateT40687T40688T40689T406903S-72150-103-20911-00-00225-025KUPARUK RIVERMWD/LWD/DDTOP OF CEMENTFINAL FIELD7-May-251Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.07.28 08:43:18 -08'00' Originated: Delivered to:19-Jun-25Alaska Oil & Gas Conservation Commiss19Jun25-NR !"#$$%$ !&$$'($)*%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED1C-158 50-029237-61-00-00 223-056 Kuparuk River WL TTiX-RST FINAL FIELD 7-Jun-251C-17 50-029228-72-00-00 198-224 Kuparuk River WL IPROF FINAL FIELD 8-Jun-253T-731 50-103209-05-00-00 224-156 Kuparuk River WL TTiX-HSD FINAL FIELD 10-Jun-253S-721 50-103209-11-00-00 225-025 Kuparuk River WL TTiX-SCMT FINAL FIELD 12-Jun-251A-22 50-029221-27-00-00 191-0003 Kuparuk River WL PPROF FINAL FIELD 17-Jun-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1Please return via courier or sign/scan and email a copy to Schlumberger."2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8" ! - +"8#!(3 . 8)"3 8#!9 3 : 8" +868 8 "8#!;" " 3 - 3" 3""+ 3 + <+3!% T40618T40619T40620T40621T406223S-72150-103209-11-00-00225-025Kuparuk RiverWLTTiX-SCMTFINAL FIELD12-Jun-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.25 08:36:59 -08'00' T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Jun 04, 2025 AOGCC Attention: Meredith Guhl 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. KRU 3S-721 Kuparuk River API #: 50-103-20911-00-00 Permit No: 225-025 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 AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Luis G Arismendi Luis.arismendi@bakerhughes.com 225-025 T40525 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.04 08:15:55 -08'00' 325-334 By Grace Christianson at 10:26 am, Jun 02, 2025 SFD 6/5/2025 RUSH SFD CDW 06/03/2025 DSR-6/3/25 10-404 VTL 6/4/2025'tϬϲͬϬϱͬϮϬϮϱ Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.05 14:58:49 -08'00'06/05/25 RBDMS JSB 061025 Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). Section 2 – Plat 20 AAC 25.283 (2)(A) Plat 1: Wells within 1/2 mile Table 1: Wells within 1/2 miles (2)(C) SECTION 3 – FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), “That portions of the aquifers on the North Slope described by a ¼ mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field”. SECTION 4 – PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5 –DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented and tested in accordance with 20 AAC 25.030. See Wellbore schematic for casing details. Wellpath 3S-721 Updated By: R. Ruysschaert, May-27-2025 7-5/8" top heavy wall 33.7ppf @ 8669.8 Ō MD / 3842 Ō TVD 7-5/8" TOC at 7918 Ō MD / 3727 Ō TVD 7-5/8'' Injector Packer 9332 Ō MD / 3953 Ō 4.5" TOL @ 9479 Ō MD / 3978 Ō TVD 4.5" liner @, 20664 Ō MD / 4203 Ō TVD Inclinations 20" shoe 0° 10 3/4" shoe 66° 7 5/8" shoe 81° 4.5" shoe 90° 7-5/8'' 29.7x33.7 ppf casing @ 9652 Ō MD / 4006 Ō TVD 3S-721 Injector As Run Base Permafrost @ 1617 Ō MD / 1573 Ō TVD Upper CompleƟon 1. StreamFlo 4-1/2" Tubing Hanger 2. 2ea GL Mandrels and 1 ea NEXA sliding sleeve 3. HES Opsis Gauge Ō MD 4. HES 7-5/8'' x 4-1/2'' TNT packer Ō MD 5. Arsenal Glass Plug 6. HES self aligning muleshoe with Baker Shear locator Lower CompleƟon (Cemented) 1. 5.5" X 7-5/8" ZXP Packer + Flex Lock V hanger 2. AU Sliding Sleeves 3. Baker Alpha sleeve 4. Citadel MOAS shoe GLM-2 @ 4990 Ō MD / 3237 Ō SS @ 9224 Ō MD / 3935 Ō TVD GLM-1 @ 2391 Ō MD / 2184 Ō 9117 9332 10-3/4" casing @ 3055 Ō MD / 2514 Ō TVD Uppermost Frac Sleeve @ 9702 Ō MD / 4014 Ō TVD SECTION 6 – ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: 10 & 3/4” casing cement pump report on 4/22/2025 shows that the original job pumped as designed. The cement job was pumped with 460 BBLs of 11.0 ppg lead cement. Mix and pump 57 BBLs 15.8 ppg of tail cement. SD and drop top plug. Pump 20 BBLs of FW with cement unit. Swap over to rig and displace cement. Lost returns at 190 BBLs into displacement. 105 BBLs cement to surface. Slow rate to 3 BPM. Bump plug at 2626 stks 262 BBLS. FCP 970 PSI. Pressure up to 1450 PSI. Check floats. Good. Cement in place @ 13:00 hrs. 4/22/25 The 7 & 5/8” casing cement report on 4/29/2025 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped pump with 50 BBLS 12.5 PPG Mud Push 5 BPM/335 PSI. Swap to cementers. Pump 72 BBLs 15.3 PPG Tail cement. Shut Down. Load top plug. Cementers pump 10 BBLS FW. Swap to rig pumps. Displace w/ rig at 5 BPM. Slow rate to 3 BPM at 50 BBLs left. Bump plug at 4644 Stks. FCP= 380 PSI. Pressure up to 1018 PSI and hold. Bleed off and check floats. Good. Full returns Cement in place at 14:50 hrs 04-29-2025. SLB SonicScope log indicates competent cement with a cement top @ 7918’ MD/ 3727’ TVD Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. 4.5" production liner cemented. No details provided here. CDW 06/03/2025 SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 4/22/2025 the 10-3/4” casing pressure was tested to 3,500 psi for 30 minutes On 5/12/2025 the 7-5/8” casing was pressure tested to 4,000 psi for 30 minutes. On 5/13/2025 the 4-1/2” tubing was pressure tested to 4,550 psi. Good Test. On 5/13/2024 the 7-5/8” casing by 4-1/2” tubing annulus was pressure tested to 3,850 psi. Good Test. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,075 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7-5/8" Annulus pressure test 3,850 4-1/2" Tubing pressure Test 4,075 Electronic PRV 8,075 Highest pump trip 7,575 5/13/2024 SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight, ppf Grade API Burst, psi API Collapse, psi 10-3/4” 45.5 L-80 5,209 2474 7-5/8” 29.7 L-80 6,885 4,789 7-5/8” 33.7 P-110S 10,860 7,870 4-1/2” 12.6 L-80 8,430 7,500 Table 2: Wellbore pressure ratings Stimulation Surface Rig-Up FMC 10K Frac Tree SECTION 9 – DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the gross Coyote interval, has an average thickness greater than 400 ft TVD over the course of the lateral section of well 3S-721, from where it intersects the top formation at 10,363’ MD to TD of the well. At the heel of the well it has a gross thickness of ~181’ thickening to ~628’ at the toe of the well. The Coyote interval is comprised of thinly interbedded sandstone and siltstone layers. The sandstone and siltstone components are litharenites, moderately to well sorted, and are of the size range from silt to very fine sand. The estimated fracture pressure for the Coyote interval is approximately 12.9-16.1 ppg based on FIT/LOT data. The immediate overlying confining interval is represented by distal toe of slope (deep marine) claystone with thin siltstone beds of the Cretaceous Seabee Formation. This interval is present in thicknesses >200’ TVD in the vicinity of the 3S-721 wellbore. The ~top of the Seabee interval starts at ~3,818’ TVDSS (8,914’ MD). It should be noted that slope to basin shales and siltstones are present from the top of the Seabee formation to the surface casing shoe at 3,065’ MD. This interval acts as a continuation of the upper confining interval. Currently, there is limited data of the fracture gradient of the overlying Seabee formation, however, further data collection is planned. CPAI has completed a LOT in the Seabee interval at 3,944’ TVDSS to 14.0 ppg equivalent mud weight (0.728 psi/ft) in the 3S-721 wellbore. CPAI also estimates the fracture closure pressure gradient to be 0.67 psi/ft based on diagnostic fracture injection testing (DFIT). The fracture gradient of the overlying Seabee formation will be greater than the fracture closure pressure gradient of 0.67 psi/ft and the leak off point of 0.73 psi/ft, per the figure below. Based on our dynamic fracture modeling, the fracture could propagate into the overlying interval, which was observed in the 3S-24B vertical well. The log results from the 3S-24B showed 34’ of potential fracture growth into the overburden compared to the >200’ TVT of the overlying zone. Additionally, geomechanical testing completed on the overburden core proved there is no remaining conductivity within a fracture that propagates into the overlying zone due to proppant embedment and interaction of the frac fluid with the rock. Post-frac injection will be at or below the fracture closure pressure (Pc) of the overlying interval which is less than the fracture propagation pressure (FPP). The lower confining interval of the Coyote comprises slope to basin floor mudstones of the Torok formation, which are present in thicknesses of ~700’ TVD in the vicinity of the 3S-721 wellbore. This same confining zone forms the upper confining interval of the Kuparuk River Unit, Torok Oil Pool. The estimated fracture gradient for this section ranges from 15-18 ppg. The base of the gross Coyote interval is estimated from seismic to be at ~4,227 ft TVDSS at the heel, and ~4,695’ ft TVDSS at the toe of the well. The estimated formation pressure within the Coyote interval is 1,674 – 1,795 psi at a depth of 4,051’ TVDSS. SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 3S-615: The 7-5/8” casing cement report on 11/13/2022 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 200 barrels of 15.3 ppg lead cement with BMII, followed with 33 barrels of 15.3 ppg tail cement, displaced with 524 barrels of 9.6 ppg mud. The plug bumped, bled off pressure and pressure and floats were confirmed to be holding. A cement bond log indicates competent cement with a cement top @ 5,620 MD (3,340’ TVD). 222-101 - Laserfiche WebLink 3S-625: The 7-5/8” casing cement report on 9/29/2022 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 264 barrels of 15.3ppg lead cement and 33 barrels of 15.3ppg tail cement. The cement was displaced with 574 barrels of 9.6ppg LSND drilling mud. The plug did not bump and 50% of shoe track volume was pumped. Losses totaled to 21 barrels during the job. Cement floats held. A cement bond log indicates competent cement with a cement top @ 7,850’ MD (3,970’ TVD). 222-079 - Laserfiche WebLink 3S-701A: The 7-5/8” casing cement report on 1/20/2023 shows that the job was pumped as designed, indicating competent cementing operations. The first stage cement job was pumped with 77 barrels of 15.3 ppg. The plug was bumped and the floats held. A cement bond log indicates competent cement with a cement top @ 6,800’ MD (3,723’ TVD). 3S-24, 3S-24A, 3S-24B: On July 23, 2023 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-24B, completing the Plug and Abandonment on October 1, 2023. A cement retainer was set at 7,680ft KB, and 25.6 bbls of Class “ G” cement was pumped through the retainer across the perforations and into the tubing, then approximately 12 bbl of cement laid in on top of the retainer. Top of Cement was tagged at 6,923ft KB, and tubing holes punched at 6,850-6,854ft KB and 6,812-6,818ft KB. The production casing by surface casing annulus ( OA) was cemented with 148 bbls of permafrost cement pumped from surface to the surface casing shoe at 4,527ft KB, then 253 bbls of Class “ G” cement was pumped down the tubing and up the tubing by production casing annulus (IA) to surface. The well was excavated to 4 ft below original ground level, tree and wellhead removed, cement top-off job performed (10gal in tubing and OA), well capped, and excavation backfilled (page 18). 221-078 - Laserfiche WebLink 3T-730: The 7-5/8” x 4-1/2” casing cement report on 4/30/2025 shows that the job was pumped with 60 barrels of 13.5ppg clean cement, 530 bbls of 13.5ppg cement with Bridge Maker II, and 60 bbls of 13.5ppg clean tail cement. The cement was displaced with 9.7ppg CI brine. The plug bumped and pressure was held at 1150 psi for 5 minutes. Pressure was then bled off and floats checked with floats holding. No losses were observed during the job. A cement bond log indicated the cement top at 4,520’ MD / 3,949’ TVD (507’ MD / 153’ TVD above the Coyote). 3T-731: The 7-5/8” x 4-1/2” casing cement report on 4/1/2025 shows that the job was pumped with 50 barrels of 14.8ppg cement, 540 bbls of 14.8ppg cement with Bridge Maker II, and 50 bbls of 14.8ppg cement. The cement was displaced with 9.6ppg CI brine. The plug bumped with pressure increasing to 1780 psi and held for 5 minutes and floats held. Losses were observed during the job. A cement bond log indicated the cement top at 12,750’ MD. Given that this cement job did not meet the criteria to stimulate the well and casing remedial cement job was pumped on 4/7/2025, the casing cement rport shows that the job was pumped with 50 bbls of 14.8ppg cement, 217 bbls of 14.8ppg cement w/ Bridge Maker II, and 253 bbls of 14.8ppg cement through the perforation at 12,725’ MD. The cement was displaced with 9.7ppg CI brine and 520bbls of fluid was lost during the job. After cement reached 500 psi compressive strength, the cement top was logged at 4,010’ MD / 3,717’ TVD (834’ MD / 389’ TVD above the Coyote). 224-156 - Laserfiche WebLink SECTION 11 – LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that no faults transect the 3S-721 wellbore. One fault transects the Coyote reservoir within one half mile radius of the 3S-721 wellbore trajectory. The trace of this fault was projected to intersect the 3T-730 wellbore at an approximate depth of 11,250’ MD, however it was not readily apparent on LWD logs. This fault is the same fault that was interpreted to be encountered at 11,700’ MD in the 3T-731 wellbore. This fault has an interpreted ~W – E strike and is downthrown to the south. In the 3T-731 well it has an interpreted throw of 10-20’. The interpreted fault should not affect overburden integrity and therefore its presence should not interfere with containment. If there is any indication that a propagated fracture has intersected the mapped fault (or any other faults unmapped to date) during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 3S-721 was completed in 2025 as a horizontal Injector in the Coyote formation. The well was completed with a 4.5” tubing upper completion and a 4.5” liner with dart actuated sliding sleeves in the lateral. Injection will be established into the well and the first stage treated. A dart will be dropped for stage 2 to initiate treatment. Once each stage is complete, a dart will be dropped for each subsequent stage. These darts will provide isolation from the previous stage and allow fracturing from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre-existing conditions. 2. Ensure the frac tree was tested to 10,000 psi on the rig. 3. Ensure all pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to ~2,000’ TVD. 4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 5. MIRU 25 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100ºF seawater. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 10,000 psi using a pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Bring up pumps and increase annulus pressure to 3,500 psi as the tubing pressures up. 10. Pump the frac job per the attached Halliburton pump schedule at 20-22 bpm with a maximum expected treating pressure of 7,075 psi. 11. RDMO Halliburton Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. The well is ready for post-frac well prep/production tree installation and flowback (after Slickline and Coiled Tubing Cleanout). Patina tracers Will be pumped in the toe and Resmetrics oil and gas tracers will be pumped in remaining stages. See Halliburton chemical disclosure sheet which includes this other chemicals. Frac Model Result: SECTION 13 – POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a de-sander unit until the fluids clean up at which time it will be turned over to production for initial clean up production. 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WZĞŐŝŽŶϭϬ͕ƚŽ^ƚĞǀĞĂǀŝĞƐ͕K'͕ĚĂƚĞĚĞĐĞŵďĞƌϮ͕ϮϬϮϰ͘ͿdŚŝƐǁĞůůĂůƐŽůŝĞƐǁŝƚŚŝŶƚŚĞďŽƵŶĚĂƌǇŽĨƚŚĞ<ƵƉĂƌƵŬZŝǀĞƌhŶŝƚƋƵŝĨĞƌǆĞŵƉƚŝŽŶŵĂƉĂƐĐƵƌƌĞŶƚůǇĚĞƉŝĐƚĞĚŽŶW^&ϲͬϯͬϮϬϮϱ ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚ<Zhϯ^ͲϳϮϭ;WdEŽ͘ϮϮϱͲϬϮϱ͖^ƵŶĚƌǇEŽ͘ϯϮϱͲϯϯϰͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϮ :ƵŶĞϱ͕ϮϬϮϱZĞŐŝŽŶϭϬ͛Ɛ͞ůĂƐŬĂKŝůΘ'ĂƐƋƵŝĨĞƌǆĞŵƉƚŝŽŶƐ/ŶƚĞƌĂĐƚŝǀĞDĂƉ͕͟ ĂǀĂŝůĂďůĞ ƚŚƌŽƵŐŚ W ZĞŐŝŽŶ ϭϬ͛Ɛ ǁĞď ƐŝƚĞ͕ 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^ĞĐƚŝŽŶ;ĂͿ;ϯͿ͕ĂďŽǀĞ͘Ϳ^&ϲͬϯͬϮϬϮϱ;ĂͿ;ϲͿ;ͿĂĐŚŚǇĚƌŽĐĂƌďŽŶǌŽŶĞŝƐŝƐŽůĂƚĞĚzĞƐ͘ŽǇŽƚĞƌĞƐĞƌǀŽŝƌĂŶĚƵƉƉĞƌĐŽŶĨŝŶŝŶŐŝŶƚĞƌǀĂůĂƌĞŝƐŽůĂƚĞĚďǇĐĞŵĞŶƚǁŝƚŚŐŽŽĚͲƋƵĂůŝƚǇďŽŶĚŝŶŐ͘^ƵƌĨĂĐĞĐĂƐŝŶŐ;ϭϬͲϯͬϰ͟ͿŝƐƐĞƚĂŶĚĐĞŵĞŶƚĞĚĂƚϯ͕Ϭϱϱ͛D;ͲϮ͕ϰϰϳ͛ds^^ͿǁŝƚŚϰϲϬďĂƌƌĞůƐŽĨϭϭ͘ϬƉƉŐůĞĂĚĐĞŵĞŶƚĂŶĚϱϳďĂƌƌĞůƐŽĨϭϱ͘ϴƉƉŐƚĂŝůĐĞŵĞŶƚ͘ƵŵƉĞĚƉůƵŐ͕ĨůŽĂƚƐŚĞůĚ͘ϭϬϱ ďĂƌƌĞůƐ ŽĨ ĐĞŵĞŶƚƌĞƚƵƌŶƐ ĂƚƐƵƌĨĂĐĞ͘ /ŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐ ;ϳͲϱͬϴ͟Ϳ ƐĞƚ Ăƚ ϵ͕ϱϮϮ͛ D ;Ͳϯ͕ϵϮϬ͛ ds^^Ϳ ĂŶĚĐĞŵĞŶƚĞĚǁŝƚŚϳϮďĂƌƌĞůƐŽĨϭϱ͘ϯƚĂŝůĐĞŵĞŶƚ͘ƵŵƉĞĚƉůƵŐ^&ϲͬϰͬϮϬϮϱ ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚ<Zhϯ^ͲϳϮϭ;WdEŽ͘ϮϮϱͲϬϮϱ͖^ƵŶĚƌǇEŽ͘ϯϮϱͲϯϯϰͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϯ :ƵŶĞϱ͕ϮϬϮϱĂŶĚ ĨůŽĂƚƐ ŚĞůĚ͘ &Ƶůů ƌĞƚƵƌŶƐ͘ /ŶƚĞƌƉƌĞƚĂƚŝŽŶ ŽĨ ĐĞŵĞŶƚĞǀĂůƵĂƚŝŽŶůŽŐŝŶĚŝĐĂƚĞƐŐŽŽĚͲƋƵĂůŝƚǇĐĞŵĞŶƚďŽŶĚŽĐĐƵƌƐĂƚĂŶĚďĞůŽǁϳ͕ϵϭϴ͛D;Ͳϯ͕ϲϲϮ͛ds^^Ϳ͘dŽƉŽǇŽƚĞƌĞƐĞƌǀŽŝƌŝƐϭϬ͕ϯϱϲ͛D;Ͳϰ͕Ϭϰϱ͛ds^^ͿĂŶĚďĂƐĞŽĨŽǇŽƚĞŝƐĂƚƚŚĞdŽĨƚŚĞǁĞůůĂƚϮϬ͕ϲϳϭ͛D;Ͳϰ͕ϭϯϵ͛ds^^Ϳ͘;ĂͿ;ϳͿWƌĞƐƐƵƌĞƚĞƐƚ͗ŝŶĨŽƌŵĂƚŝŽŶĂŶĚƉƌĞƐƐƵƌĞͲƚĞƐƚƉůĂŶƐĨŽƌĐĂƐŝŶŐĂŶĚƚƵďŝŶŐŝŶƐƚĂůůĞĚŝŶǁĞůůWƌŽǀŝĚĞĚ ǁŝƚŚ ĂƉƉůŝĐĂƚŝŽŶ͘ϯϴϱϬ ƉƐŝ D/d/͕ ϰϬϳϱ ƉƐŝ D/ddƉůĂŶ͘tϬϲͬϬϯͬϮϬϮϱ;ĂͿ;ϴͿWƌĞƐƐƵƌĞƌĂƚŝŶŐƐĂŶĚƐĐŚĞŵĂƚŝĐƐ͗ǁĞůůďŽƌĞ͕ǁĞůůŚĞĂĚ͕KW͕ƚƌĞĂƚŝŶŐŚĞĂĚWƌŽǀŝĚĞĚ ǁŝƚŚ ĂƉƉůŝĐĂƚŝŽŶ͘ ϭϬ< ƉƐŝ ĨƌĂĐ ƚƌĞĞ͕ ŵĂǆ͘ ĨƌĂĐ͘WƌĞƐƐƵƌĞϳϬϳϱƉƐŝ͘WƵŵƉŬŶŽĐŬŽƵƚϳϱϳϱĂŶĚ'KZsϴϬϳϱƉƐŝ͕͘ƚƌĞĞƚĞƐƚϭϬϬϬϬƉƐŝ͕ůŝŶĞƐƚĞƐƚϭϬϬϬϬƉƐŝ͘tϬϲͬϬϯͬϮϬϮϱ;ĂͿ;ϵͿ;Ϳ&ƌĂĐƚƵƌŝŶŐĂŶĚĐŽŶĨŝŶŝŶŐǌŽŶĞƐ͗ůŝƚŚŽůŽŐŝĐĚĞƐĐƌŝƉƚŝŽŶĨŽƌĞĂĐŚǌŽŶĞ;ĂͿ;ϵͿ;Ϳ'ĞŽůŽŐŝĐĂůŶĂŵĞŽĨĞĂĐŚǌŽŶĞ;ĂͿ;ϵͿ;ͿĂŶĚ;ĂͿ;ϵͿ;ͿDĞĂƐƵƌĞĚĂŶĚƚƌƵĞǀĞƌƚŝĐĂůĚĞƉƚŚƐ;ĂͿ;ϵͿ;Ϳ&ƌĂĐƚƵƌĞƉƌĞƐƐƵƌĞĨŽƌĞĂĐŚǌŽŶĞhƉƉĞƌĐŽŶĨŝŶŝŶŐǌŽŶĞƐ͗ϮϬϬ͛ƚƌƵĞͲǀĞƌƚŝĐĂůƚŚŝĐŬŶĞƐƐ;dsdͿŽĨĐůĂǇƐƚŽŶĞ ǁŝƚŚ ƚŚŝŶ ƐŝůƚƐƚŽŶĞ ďĞĚƐ ĂƐƐŝŐŶĞĚ ƚŽ ƚŚĞ^ĞĂďĞĞĨŽƌŵĂƚŝŽŶ͕ǁŚŝĐŚŚĂƐĂƚŽƉĂƚϴ͕ϵϭϴ͛D;Ͳϯ͕ϴϭϴ͛ds^^Ϳ͘&ƌĂĐƚƵƌĞŐƌĂĚŝĞŶƚŝƐĞǆƉĞĐƚĞĚƚŽƌĂŶŐĞĨƌŽŵĂďŽƵƚϬ͘ϲϳƚŽϬ͘ϳϮϴƉƐŝͬĨƚ;ϭϮ͘ϵƚŽϭϰ͘ϬƉƉŐDtͿ͘&ƌĂĐƚƵƌŝŶŐŽŶĞ͗dŚĞƚŽƉŽĨƚŚĞŽǇŽƚĞƌĞƐĞƌǀŽŝƌŝƐĂƚϭϬ͕ϯϱϲ͛D;Ͳϰ͕Ϭϰϱds^^ͿĂŶĚŝƚĐŽŶƐŝƐƚƐŽĨĂŶŝŶƚĞƌǀĂůŽĨƚŚŝŶůǇŝŶƚĞƌďĞĚĚĞĚƐĂŶĚƐƚŽŶĞĂŶĚƐŝůƚƐƚŽŶĞƚŚĂƚƌĂŶŐĞƐĨƌŽŵϭϴϬ͛ƚŽϲϯϬ͛dsdŝŶƚŚŝƐĂƌĞĂ͘&ƌĂĐƚƵƌĞŐƌĂĚŝĞŶƚĞǆƉĞĐƚĞĚƚŽďĞĂďŽƵƚϬ͘ϲϮƉƐŝͬĨƚ;ϭϭ͘ϵƉƉŐDtͿ͘>ŽǁĞƌĐŽŶĨŝŶŝŶŐǌŽŶĞƐ͗dŽƌŽŬĨŽƌŵĂƚŝŽŶƐůŽƉĞƚŽďĂƐŝŶĨůŽŽƌŵƵĚƐƚŽŶĞƐǁŝƚŚĂŶĂŐŐƌĞŐĂƚĞdsdŽĨĂďŽƵƚϳϬϬ͛͘dŚĞƚŽƉŽĨƚŚĞůŽǁĞƌĐŽŶĨŝŶŝŶŐǌŽŶĞƐŝƐĞƐƚŝŵĂƚĞĚƚŽůŝĞĨƌŽŵͲϰ͕ϮϮϳ͛ƚŽʹϰ͕ϲϵϱ͛ds^^͘&ƌĂĐƚƵƌĞŐƌĂĚŝĞŶƚĞǆƉĞĐƚĞĚƚŽƌĂŶŐĞĨƌŽŵĂďŽƵƚϬ͘ϳϴƚŽϬ͘ϵϰƉƐŝͬĨƚ;ϭϱ͘ϬƚŽϭϴ͘ϬƉƉŐDtͿ͘^&ϲͬϰͬϮϬϮϱ;ĂͿ;ϭϬͿ>ŽĐĂƚŝŽŶ͕ŽƌŝĞŶƚĂƚŝŽŶ͕ƌĞƉŽƌƚŽŶŵĞĐŚĂŶŝĐĂůĐŽŶĚŝƚŝŽŶŽĨĞĂĐŚǁĞůůƚŚĂƚŵĂǇƚƌĂŶƐĞĐƚƚŚĞĐŽŶĨŝŶŝŶŐǌŽŶĞƐĂŶĚƐƵĨĨŝĐŝĞŶƚŝŶĨŽƌŵĂƚŝŽŶƚŽĚĞƚĞƌŵŝŶĞǁĞůůƐ/ƚŝƐŚŝŐŚůǇƵŶůŝŬĞůǇƚŚĂƚĂŶǇŽĨƚŚĞǁĞůůƐŽƌǁĞůůďŽƌĞƐǁŝƚŚŝŶĂЪͲŵŝůĞƌĂĚŝƵƐǁŝůůŝŶƚĞƌĨĞƌĞǁŝƚŚŚǇĚƌĂƵůŝĐĨƌĂĐƚƵƌŝŶŐĨůƵŝĚƐĨƌŽŵƚŚŝƐŽƉĞƌĂƚŝŽŶďĞĐĂƵƐĞŽĨĐĞŵĞŶƚŝƐŽůĂƚŝŽŶĂŶĚͬŽƌƐĞƉĂƌĂƚŝŽŶĚŝƐƚĂŶĐĞ͘ ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚ<Zhϯ^ͲϳϮϭ;WdEŽ͘ϮϮϱͲϬϮϱ͖^ƵŶĚƌǇEŽ͘ϯϮϱͲϯϯϰͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϰ :ƵŶĞϱ͕ϮϬϮϱǁŝůůŶŽƚŝŶƚĞƌĨĞƌĞǁŝƚŚĐŽŶƚĂŝŶŵĞŶƚŽĨŚǇĚƌĂƵůŝĐĨƌĂĐƚƵƌŝŶŐĨůƵŝĚǁŝƚŚŝŶЪŵŝůĞŽĨƚŚĞƉƌŽƉŽƐĞĚǁĞůůďŽƌĞƚƌĂũĞĐƚŽƌǇdŚĞƌĞĂƌĞĞŝŐŚƚ;ϴͿǁĞůůƐ;ŝŶĐůƵĚŝŶŐƐŝĚĞƚƌĂĐŬƐͿǁŝƚŚŝŶЪŵŝůĞŽĨ<Zhϯ^ͲϳϮϭƚŚĂƚƉĞŶĞƚƌĂƚĞƚŚĞĐŽŶĨŝŶŝŶŐŝŶƚĞƌǀĂůƐ͘W/ŚĂƐĞǀĂůƵĂƚĞĚĞĂĐŚǁĞůůĂŶĚƉƌŽǀŝĚĞĚĐĞŵĞŶƚŝŶŐĂŶĚůŽŐŐŝŶŐŝŶĨŽƌŵĂƚŝŽŶŽĨŝƐŽůĂƚŝŽŶŽĨƐƵƌĨĂĐĞĂŶĚŽǇŽƚĞǌŽŶĞƐ͘K'ĞǀĂůƵĂƚĞĚĂůůǁĞůůƐƚŚĂƚŵĂǇƚƌĂŶƐĞĐƚƚŚĞĐŽŶĨŝŶŝŶŐǌŽŶĞƐǁŝƚŚŝŶƚŚĞ<Zhϯ^ͲϳϮϭƌĞĂŽĨZĞǀŝĞǁĂŶĚĨŽƵŶĚŝƚŚŝŐŚůǇ ƵŶůŝŬĞůǇ ƚŚĂƚ ĂŶǇ ŽĨ ƚŚĞƐĞ ǁĞůůƐ ǁŝůů ŝŶƚĞƌĨĞƌĞ ǁŝƚŚĨƌĂĐƚƵƌŝŶŐĨůƵŝĚƐĚƵĞƚŽĐĞŵĞŶƚͲŝƐŽůĂƚŝŽŶĂŶĚͬŽƌƐĞƉĂƌĂƚŝŽŶĚŝƐƚĂŶĐĞŽƌĚŝƌĞĐƚŝŽŶ͘tϬϲͬϬϯͬϮϬϮϱ^&ϲͬϱͬϮϬϮϱ;ĂͿ;ϭϭͿ&ĂƵůƚƐĂŶĚĨƌĂĐƚƵƌĞƐ͕^ƵĨĨŝĐŝĞŶƚŝŶĨŽƌŵĂƚŝŽŶƚŽĚĞƚĞƌŵŝŶĞŶŽŝŶƚĞƌĨĞƌĞŶĐĞǁŝƚŚĐŽŶƚĂŝŶŵĞŶƚŽĨƚŚĞŚǇĚƌĂƵůŝĐĨƌĂĐƚƵƌŝŶŐĨůƵŝĚǁŝƚŚŝŶЪŵŝůĞŽĨƚŚĞƉƌŽƉŽƐĞĚǁĞůůďŽƌĞƚƌĂũĞĐƚŽƌǇ/ƚŝƐƵŶůŝŬĞůǇƚŚĂƚĂŶǇĨĂƵůƚƐŽƌĨƌĂĐƚƵƌĞƐǁŝůůŝŶƚĞƌĨĞƌĞǁŝƚŚĐŽŶƚĂŝŶŵĞŶƚŽĨƚŚĞŝŶũĞĐƚĞĚĨƌĂĐƚƵƌŝŶŐĨůƵŝĚƐ͖ŚŽǁĞǀĞƌ͕ŝĨƚŚĞƌĞĂƌĞŝŶĚŝĐĂƚŝŽŶƐƚŚĂƚĂĨƌĂĐƚƵƌĞŚĂƐŝŶƚĞƌƐĞĐƚĞĚĂĨĂƵůƚŽƌ ŶĂƚƵƌĂůͲĨƌĂĐƚƵƌĞ ŝŶƚĞƌǀĂů ĚƵƌŝŶŐ ĨƌĂĐ ŽƉĞƌĂƚŝŽŶƐ͕ ƚŚĞŽƉĞƌĂƚŽƌ ǁŝůů ŐŽ ƚŽ ĨůƵƐŚ ĂŶĚ ƚĞƌŵŝŶĂƚĞ ƚŚĞ ƐƚĂŐĞŝŵŵĞĚŝĂƚĞůǇ͘dŚĞŽƉĞƌĂƚŽƌŚĂƐŝĚĞŶƚŝĨŝĞĚŽŶĞĨĂƵůƚƚŚƌŽƵŐŚƐĞŝƐŵŝĐŽƌǁĞůůĚĂƚĂǁŝƚŚŝŶĂЪͲŵŝůĞƌĂĚŝƵƐŽĨ<Zhϯ^ͲϳϮϭ͘dŚŝƐǁĞƐƚͲƚŽͲĞĂƐƚƐƚƌŝŬŝŶŐĨĂƵůƚŝƐĞƐƚŝŵĂƚĞĚƚŽŚĂǀĞϭϬ͛ƚŽϮϬ͛ŽĨǀĞƌƚŝĐĂůĚŝƐƉůĂĐĞŵĞŶƚ͘/ƚůŝĞƐĂďŽƵƚϬ͘ϰŵŝůĞƐŶŽƌƚŚŽĨƚŚĞŽǇŽƚĞƌĞƐĞƌǀŽŝƌ ŽƉĞŶĞĚ ƚŽ ϯ^ͲϳϮϭ͕ ĂŶĚ ďĞĐĂƵƐĞ ŽĨ ŝƚƐ͕ ůŽĐĂƚŝŽŶ͕ǁĞƐƚͲƚŽͲĞĂƐƚƐƚƌŝŬĞŽƌŝĞŶƚĂƚŝŽŶ͕ĂŶĚƐĞƉĂƌĂƚŝŽŶĚŝƐƚĂŶĐĞ͕ŝƚǁŝůůŶŽƚŝŶƚĞƌĨĞƌĞǁŝƚŚĨƌĂĐƚƵƌŝŶŐŽƌŝŶũĞĐƚŝŽŶĂĐƚŝǀŝƚŝĞƐŝŶϯ^ͲϳϮϭ͘^&ϲͬϰͬϮϬϮϱ;ĂͿ;ϭϮͿWƌŽƉŽƐĞĚƉƌŽŐƌĂŵĨŽƌĨƌĂĐƚƵƌŝŶŐŽƉĞƌĂƚŝŽŶWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘tϬϲͬϬϯͬϮϬϮϱ;ĂͿ;ϭϮͿ;ͿƐƚŝŵĂƚĞĚǀŽůƵŵĞWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘ϰϬ͕ϬϬϬďďůƚŽƚĂůĚŝƌƚǇǀŽů͘ϲDůďƚŽƚĂůƉƌŽƉƉĂŶƚ͘ϮϭƐƚĂŐĞͬŝŶƚĞƌǀĂůƐ͘ŝŐ&ƌĂĐ͘tϬϲͬϬϯͬϮϬϮϱ;ĂͿ;ϭϮͿ;ͿĚĚŝƚŝǀĞƐ͗ŶĂŵĞƐ͕ƉƵƌƉŽƐĞƐ͕ĐŽŶĐĞŶƚƌĂƚŝŽŶƐWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘tϬϲͬϬϯͬϮϬϮϱ ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚ<Zhϯ^ͲϳϮϭ;WdEŽ͘ϮϮϱͲϬϮϱ͖^ƵŶĚƌǇEŽ͘ϯϮϱͲϯϯϰͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϱ :ƵŶĞϱ͕ϮϬϮϱ;ĂͿ;ϭϮͿ;ͿŚĞŵŝĐĂůŶĂŵĞĂŶĚ^ŶƵŵďĞƌŽĨĞĂĐŚWƌŽǀŝĚĞĚ ǁŝƚŚ ĂƉƉůŝĐĂƚŝŽŶ͘ WĂƚŝŶĂ͕ ZĞƐŵĞƚƌŝĐƐ͕ ĂŶĚ,ĂůůŝďƵƌƚŽŶĚŝƐĐůŽƐƵƌĞƉƌŽǀŝĚĞĚ͘WƌŽƉƌŝĞƚĂƌǇĐŚĞŵŝĐĂůƐŽŶĨŝůĞĂƚK'͘tϬϲͬϬϯͬϮϬϮϱ;ĂͿ;ϭϮͿ;Ϳ/ŶĞƌƚƐƵďƐƚĂŶĐĞƐ͕ǁĞŝŐŚƚŽƌǀŽůƵŵĞŽĨĞĂĐŚWƌŽǀŝĚĞĚǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘tϬϲͬϬϯͬϮϬϮϱ;ĂͿ;ϭϮͿ;ͿDĂǆŝŵƵŵƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞǁŝƚŚƐƵƉƉŽƌƚŝŶŐŝŶĨŽƚŽĚĞƚĞƌŵŝŶĞĂƉƉƌŽƉƌŝĂƚĞŶĞƐƐĨŽƌƉƌŽŐƌĂŵ^ŝŵƵůĂƚŝŽŶƐŚŽǁƐŵĂǆƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞϳϬϳϱƉƐŝ͘ƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞ͘ DĂǆ ƉƌĞƐƐƵƌĞ ŝƐϳϱϳϱ ƉƐŝ ƚŽ ϴϬϳϱƉƐŝ ƚŽ WƵŵƉƐŚƵƚĚŽǁŶ͘tŝƚŚϯϱϬϬƉƐŝďĂĐŬƉƌĞƐƐƵƌĞ/;/ƉŽƉŽĨĨƐĞƚϯϲϬϬƉƐŝͿ͕ŵĂǆƚƵďŝŶŐĚŝĨĨĞƌĞŶƚŝĂůƐŚŽƵůĚďĞϯϱϳϱƉƐŝ͘tϬϲͬϬϯͬϮϬϮϱ;ĂͿ;ϭϮͿ;&Ϳ&ƌĂĐƚƵƌĞƐʹŚĞŝŐŚƚ͕ůĞŶŐƚŚ͕DĂŶĚdsƚŽƚŽƉ͕ĚĞƐĐƌŝƉƚŝŽŶŽĨĨƌĂĐƚƵƌŝŶŐŵŽĚĞůEŽŶĞŽĨƚŚĞŝŶĚƵĐĞĚĨƌĂĐƚƵƌĞƐǁŝůůƉĞŶĞƚƌĂƚĞƚŚƌŽƵŐŚƚŚĞĐŽŶĨŝŶŝŶŐ ŝŶƚĞƌǀĂůƐ͘dŚĞ ĂŶƚŝĐŝƉĂƚĞĚ ŚĂůĨͲůĞŶŐƚŚƐ ŽĨ ƚŚĞŝŶĚƵĐĞĚĨƌĂĐƚƵƌĞƐǁŝůůƌĂŶŐĞĨƌŽŵϯϱϬ͛ƚŽϰϮϬ͛ĂĐĐŽƌĚŝŶŐƚŽƚŚĞKƉĞƌĂƚŽƌ͛ƐĐŽŵƉƵƚĞƌƐŝŵƵůĂƚŝŽŶ͘ŽŵƉƵƚĞƌƐŝŵƵůĂƚŝŽŶŝŶĚŝĐĂƚĞƐƚŚĞĂŶƚŝĐŝƉĂƚĞĚŚĞŝŐŚƚŽĨƚŚĞŝŶĚƵĐĞĚĨƌĂĐƚƵƌĞƐǁŝůůďĞĂďŽƵƚϭϴϬ͕͛ǁŝƚŚĂƐŚĂůůŽǁĞƐƚds^^ŽĨĂďŽƵƚʹϰ͕ϬϭϮ͛ĂŶĚĚĞĞƉĞƐƚds^^ŽĨĂďŽƵƚͲϰ͕ϮϯϮ͛͘dŚĞƚŽƉŽĨƚŚĞŽǇŽƚĞŝƐʹϰ͕Ϭϰϱ͛ ds^^͘ dŚĞƚŚŝĐŬŶĞƐƐŽĨƚŚĞƌĞƐĞƌǀŽŝƌǀĂƌŝĞƐ ĨƌŽŵĂďŽƵƚϭϴϬ͛ĂƚƚŚĞŚĞĞůŽĨƚŚĞǁĞůů;ďĂƐĞŽǇŽƚĞĂƚʹϰ͕ϮϮϱ͛ds^^ͿƚŽĂďŽƵƚϲϯϬ͛ĂƚƚŚĞƚŽĞŽĨƚŚĞǁĞůů;ďĂƐĞŽǇŽƚĞĂƚʹϰ͕ϲϯϮ͛ds^^Ϳ͘^Ž͕ďĞŝŶŐϭϴϬ͛ŝŶŵŽĚĞůĞĚŚĞŝŐŚƚ͕ƐŽŵĞŽĨƚŚĞŝŶĚƵĐĞĚĨƌĂĐƚƵƌĞƐŵĂǇƉĞŶĞƚƌĂƚĞĂĨĞǁĨĞĞƚŝŶƚŽƚŚĞŽǀĞƌůǇŝŶŐ^ĞĂďĞĞ ĂŶĚ ƐŽŵĞ ŵĂǇ ƉĞŶĞƚƌĂƚĞ Ă ĨĞǁ ĨĞĞƚŝŶƚŽ ƚŚĞƵŶĚĞƌůǇŝŶŐ dŽƌŽŬ͕ ďƵƚ ŶŽŶĞ ŽĨ ƚŚĞ ŝŶĚƵĐĞĚĨƌĂĐƚƵƌĞƐ ǁŝůůƉĞŶĞƚƌĂƚĞƚŚƌŽƵŐŚĞŝƚŚĞƌŽĨƚŚĞƐĞƚŚŝĐŬ͕ĐŽŶĨŝŶŝŶŐŝŶƚĞƌǀĂůƐ͘^&ϲͬϰͬϮϬϮϱ;ĂͿ;ϭϯͿWƌŽƉŽƐĞĚƉƌŽŐƌĂŵĨŽƌƉŽƐƚͲĨƌĂĐƚƵƌŝŶŐǁĞůůĐůĞĂŶƵƉĂŶĚĨůƵŝĚƌĞĐŽǀĞƌǇtĞůů ĐůĞĂŶŽƵƚ ĂŶĚ ĨůŽǁďĂĐŬ ƉƌŽĐĞĚƵƌĞ ƉƌŽǀŝĚĞĚ ǁŝƚŚĂƉƉůŝĐĂƚŝŽŶ͘EŽĚŝƐƉŽƐĂůŝĚĞŶƚŝĨŝĞĚďƵƚϯ^ŚĂƐƌŽĂĚĚŝƐƉŽƐĂůŽƉƚŝŽŶƐ͘tϬϲͬϬϯͬϮϬϮϱ;ďͿdĞƐƚŝŶŐŽĨĐĂƐŝŶŐŽƌŝŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐdĞƐƚĞĚхϭϭϬйŽĨŵĂǆĂŶƚŝĐŝƉĂƚĞĚƉƌĞƐƐƵƌĞϯϱϬϬƉƐŝďĂĐŬƉƌĞƐƐƵƌĞ͕ϱͬϭϯͬϮϬϮϱ͍ƚĞƐƚƚŽϯϴϱϬƉƐŝ͕ƉŽƉŽĨĨƐĞƚĂƐϯϲϬϬƉƐŝtϬϲͬϬϯͬϮϬϮϱ ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚ<Zhϯ^ͲϳϮϭ;WdEŽ͘ϮϮϱͲϬϮϱ͖^ƵŶĚƌǇEŽ͘ϯϮϱͲϯϯϰͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϲ :ƵŶĞϱ͕ϮϬϮϱ;ĐͿ&ƌĂĐƚƵƌŝŶŐƐƚƌŝŶŐ;ĐͿ;ϭͿWĂĐŬĞƌхϭϬϬ͛ďĞůŽǁdKŽĨƉƌŽĚƵĐƚŝŽŶŽƌŝŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐϰ͘ϱ͟ƚƵďŝŶŐǁŝůůďĞĂŶĐŚŽƌĞĚǁŝƚŚĂƌĞƚƌŝĞǀĂďůĞƉĂĐŬĞƌƐĞƚĂƚĂƉƉƌŽǆ͘ϵϯϯϮĨƚǁŝƚŚƵƉƉĞƌŵŽƐƚĨƌĂĐƐůĞĞǀĞĂƚϵϳϬϮĨƚ͘ϳͲϱͬϴ͟dKŽĨϳϵϭϴŵĂŬĞƐƉĂĐŬĞƌƐĞƚϭϰϭϰĨƚďĞůŽǁdK͘,ŽƌŝǌŽŶƚĂů ĐŽŵƉůĞƚŝŽŶ ĂƉƉƌŽǆ͘ ϱϬ Ĩƚ ds ĨƌĂĐ ƐůĞĞǀĞ ƚŽƉĂĐŬĞƌƐ͘͘^ŽŶŝĐ^ĐŽƉĞĐŽŶƐĞƌǀĂƚŝǀĞůǇ ƐŚŽǁƐ ŐŽŽĚ ĐĞŵĞŶƚ Ăƚ ĂƌĞĂ 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ƚŚĞŽƉĞƌĂƚŽƌƐŚĂůů͗tϬϲͬϬϯͬϮϬϮϱ;ŐͿ;ϭͿEŽƚŝĨǇK'ǁŝƚŚŝŶϮϰŚŽƵƌƐ;ŐͿ;ϮͿŽƌƌĞĐƚŝǀĞĂĐƚŝŽŶŽƌƐƵƌǀĞŝůůĂŶĐĞ;ŐͿ;ϯͿ^ƵŶĚƌǇƚŽK';ŚͿ^ƵŶĚƌǇZĞƉŽƌƚ;ŝͿZĞƉŽƌƚŝŶŐ;ŝͿ;ϭͿ&ƌĂĐ&ŽĐƵƐZĞƉŽƌƚŝŶŐ ϮϬϮϱ͘Ϯϴϯ,ǇĚƌĂƵůŝĐ&ƌĂĐƚƵƌŝŶŐƉƉůŝĐĂƚŝŽŶʹŚĞĐŬůŝƐƚ<Zhϯ^ͲϳϮϭ;WdEŽ͘ϮϮϱͲϬϮϱ͖^ƵŶĚƌǇEŽ͘ϯϮϱͲϯϯϰͿWĂƌĂŐƌĂƉŚ^ƵďͲWĂƌĂŐƌĂƉŚ^ĞĐƚŝŽŶŽŵƉůĞƚĞ͍K' WĂŐĞϳ :ƵŶĞϱ͕ϮϬϮϱ;ŝͿ;ϮͿK'ZĞƉŽƌƚŝŶŐ͗ƉƌŝŶƚĞĚΘĞůĞĐƚƌŽŶŝĐ;ũͿWŽƐƚͲĨƌĂĐǁĂƚĞƌƐĂŵƉůŝŶŐƉůĂŶEŽƚƌĞƋƵŝƌĞĚ;ƐĞĞ^ĞĐƚŝŽŶ;ĂͿ;ϯͿ͕ĂďŽǀĞͿ͘^&ϲͬϰͬϮϬϮϱ;ŬͿŽŶĨŝĚĞŶƚŝĂůŝŶĨŽƌŵĂƚŝŽŶůĞĂƌůǇŵĂƌŬĞĚĂŶĚƐƉĞĐŝĨŝĐĨĂĐƚƐƐƵƉƉŽƌƚŝŶŐŶŽŶĚŝƐĐůŽƐƵƌĞEŽŶͲĐŽŶĨŝĚĞŶƚŝĂůǁĞůů͘^&ϲͬϰͬϮϬϮϱ;ůͿsĂƌŝĂŶĐĞƐƌĞƋƵĞƐƚĞĚDŽĚŝĨŝĐĂƚŝŽŶƐŽĨĚĞĂĚůŝŶĞƐ͕ƌĞƋƵĞƐƚƐĨŽƌǀĂƌŝĂŶĐĞƐŽƌǁĂŝǀĞƌƐEŽƉůĂŶĨŽƌƉŽƐƚĨƌĂĐƚƵƌĞǁĂƚĞƌǁĞůůĂŶĂůǇƐŝƐ͘ŽŵŵŝƐƐŝŽŶŵĂǇƌĞƋƵŝƌĞƚŚŝƐĚĞƉĞŶĚŝŶŐŽŶƉĞƌĨŽƌŵĂŶĐĞŽĨƚŚĞĨƌĂĐƚƵƌŝŶŐŽƉĞƌĂƚŝŽŶ͘ SAMPLE TRANSMITTAL TO: AOGCC 333 WEST 7TH SUITE 100 ANCH. AK. 99501 279-1433 OPERATOR: CPAI SAMPLE TYPE: Dry Cuttings SAMPLES SENT: 3S-721 9600 - 20670 5 Boxes SENT BY: M. McCRACKEN aas- OzS (� 33 DATE: 05/1912025 AIR BILL: N/A CPAL CPA12025051901 CHARGE CODE: N/A NAME: 3S-721 NUMBER OF BOXES: 5 Boxes UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY OF THIS FORM TO: CONOCOPHILLIPS, ALASKA 700 G ST ATO-380 ANCHORAGE, AK. 99510 ATTN:MIKE McCRACKEN Mike.mccracken@conocophillips.com RECHVE® MAY 19 2025 AOGCC 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 ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, Alaska, 99510 Re: Kuparuk River Field, Coyote Oil Pool, KRU 3S-721 ConocoPhillips Alaska Inc. Permit to Drill Number: 225-025 Surface Location: 2550' FNL, 1203' FEL, S18 T12N R8E, UM Bottomhole Location: 2559' FSL, 2018' FWL, S25 T12N R7E, 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, Jessie L. Chmielowski Commissioner DATED this 10th day of April, 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.10 14:13:27 -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: 20,671 TVD: 4205 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): 64.3 15. Distance to Nearest Well Open Surface: x- 476057 y- 5993866 Zone- 4 24.8 to Same Pool: 2524' to 3S-701A 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90.5 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94# H40 Welded 92 40 40 92 92 13-1/2" 10-3/4" 45.5# L80 H563 3048 40 40 3048 2525 9-7/8" 7-5/8" 29.7#L80 H563 9253 40 40 9253 3865 9-7/8" 7-5/8" 33.7# P110S H563 800 9253 3865 10053 4072 6-1/2" 4-1/2" 12.6# P110-S H563 10793 9878 4046 20671 4205 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20.Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Chris Brillon Contact Email:trevor.kelley@cop.com Wells Engineering Manager Contact Phone: 281-513-5789 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 1924 P.O. Box 100360 Anchorage, Alaska, 99510-0360 2550 FNL, 1203 FEL, S18 T12N R8E, UM ADL380107 / ADL025544 / ADL025551 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips Alaska Inc 59-52-180 KRU 3S-721 2452 FSL, 1013 FWL, S13 T12N R7E, UM 932060000, 931869000, 931851000 2559 FSL, 2018 FWL, S25 T12N R7E, UM 2448 / 2560 / 2560 GL / BF Elevation above MSL (ft): 18. Casing Program:Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks (including stage data) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Casing Length Size Cement Volume MD Intermediate Surface Conductor/Structural Perforation Depth MD (ft): Perforation Depth TVD (ft): Liner Production 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. Kuparuk River Field Coyote Oil Pool 4/19/2025 2717' to ADL025544 1251 sx of 15.3 ppg Class G + Add's 383 sx of 15.3 ppg Class G + 17 sx of 15.3 ppg Class G Cement to surface with 4 yds slurry 1226 sx of 11.0 ppg DeepCRETE + 272 sx of 15.8 ppg Class G 1504 Stratigraphic Test No Mud log req'd: Yes No No Directional svy req'd: Yes No Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Single Well Gas Hydrates No Inclination-only svy req'd: Yes No Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal No No &ŽƌŵϭϬͲϰϬϭZĞǀŝƐĞĚϯͬϮϬϮϭ This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Grace Christianson at 8:15 am, Mar 19, 2025 50-103-20911-00-00 DivertervariancegranteGper20AAC25.035(h)(2) x A.Dewhurst 10APR25 Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig Annular preventer test to 2500 psig Intermediate I cement evaluation may use SonicScope under the attached Conditions of Approval Surface casing LOT and annular LOT to the AOGCC as soon as available BOPE testing on a 21-day interval is approved with the attached conditions Review results of cement evaluation logs with AOGCC before proceeding. VTL 4/10/2025 DSR-3/28/25 4/15/2025 225-025 ($8 4/10/2025 4/10/2025Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.10 14:13:42 -08'00' RBDMS JSB 041125 <Zhϯ^ͲϳϮϭ Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPAI will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. .58'66 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. 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3.WƌŽƉŽƐĞĚĚƌŝůůŝŶŐĨůƵŝĚƐƉƌŽŐƌĂŵƐƵŵŵĂƌǇ 4.WƌŽƉŽƐĞĚĐŽŵƉůĞƚŝŽŶĚŝĂŐƌĂŵ 5.WƌĞƐƐƵƌĞŝŶĨŽƌŵĂƚŝŽŶĂƐƌĞƋƵŝƌĞĚďǇϮϬϮϱ͘ϬϬϱ;ĐͿ;ϰͿ;ĂͲĐͿ 6.ŝƌĞĐƚŝŽŶĂůĚƌŝůůŝŶŐͬĐŽůůŝƐŝŽŶĂǀŽŝĚĂŶĐĞŝŶĨŽƌŵĂƚŝŽŶĂƐƌĞƋƵŝ ƌĞĚďǇϮϬϮϱ͘ϬϱϬ;ďͿ /ŶĨŽƌŵĂƚŝŽŶƉĞƌƚŝŶĞŶƚƚŽƚŚĞĂƉƉůŝĐĂƚŝŽŶƚŚĂƚŝƐƉƌĞƐĞŶƚůǇŽŶĨŝůĞĂƚƚŚĞK'͗ 1.ŝĂŐƌĂŵƐŽĨƚŚĞKWĞƋƵŝƉŵĞŶƚ͕ĚŝǀĞƌƚĞƌĞƋƵŝƉŵĞŶƚĂŶĚĐŚŽŬĞŵĂŶŝĨŽůĚůĂǇŽƵƚĂƐƌĞƋƵŝƌĞĚďǇϮϬ Ϯϱ͘Ϭϯϱ;ĂͿĂŶĚ;ďͿ͘ 2.ĚĞƐĐƌŝƉƚŝŽŶŽĨƚŚĞĚƌŝůůŝŶŐĨůƵŝĚƐŚĂŶĚůŝŶŐƐǇƐƚĞŵ͘ 3.ŝĂŐƌĂŵŽĨƌŝƐĞƌƐĞƚƵƉ͘ /ĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐŽƌƌĞƋƵŝƌĞĨƵƌƚŚĞƌŝŶĨŽƌŵĂƚŝŽŶ͕ƉůĞĂƐĞĐŽŶƚĂĐƚdƌĞǀŽƌ<ĞůůĞǇĂƚϮϴϭͲϱϭϯͲϲϳϴϵ ;ĂďďǇ͘ǁĂƌƌĞŶΛĐŽƉ͘ĐŽŵͿŽƌŚƌŝƐƌŝůůŽŶĂƚϵϬϳͲϮϲϱͲϲϭϮϬ͘ ^ŝŶĐĞƌĞůǇ͕ĐĐ͗ ϯ^ͲϳϮϭtĞůů&ŝůĞͬ:ĞŶŶĂdĂǇůŽƌ dKϭϴϬϰ tŝůůĂƌŚĂƌƚ dKϭϱϱϮ dƌĞǀŽƌ<ĞůůĞǇŚƌŝƐƌŝůůŽŶ dKϭϱϰϴ ƌŝůůŝŶŐŶŐŝŶĞĞƌ ǀĂƌŝĂŶĐĞŽĨƚŚĞĚŝǀĞƌƚĞƌƌĞƋƵŝƌĞŵĞŶƚƵŶĚĞƌϮϬϮϱ͘Ϭϯϱ;ŚͿ;ϮͿ Recommend granting variance. -A.Dewhurst 10APR25 ϯ^ͲϳϮϭK'ϭϬͲϰϬϭW ϯͬϭϴͬϮϬϮϱ ϯ^ͲϳϮϭK'ϭϬͲϰϬϭWϭͮϭϯ ϯ^ͲϳϮϭtĞůůWůĂŶ ƉƉůŝĐĂƚŝŽŶĨŽƌWĞƌŵŝƚƚŽƌŝůů dĂďůĞŽĨŽŶƚĞŶƚƐ 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ϯ^ͲϳϮϭK'ϭϬͲϰϬϭWϯͮϭϯ tĞůůWůĂƚ ϯ^ͲϳϮϭK'ϭϬͲϰϬϭW ϯͬϭϴͬϮϬϮϱ ϯ^ͲϳϮϭK'ϭϬͲϰϬϭWϰͮϭϯ ϯ͘ WƌŽƉŽƐĞĚƌŝůůŝŶŐWƌŽŐƌĂŵ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϭϯͿ ϭ͘ D/ZhŽǇŽŶϮϱŽŶƚŽǁĞůůŽǀĞƌƉƌĞͲŝŶƐƚĂůůĞĚϮϬ͟ŝŶƐƵůĂƚĞĚĐŽŶĚƵĐ ƚŽƌ͘ Ϯ͘ ZŝŐƵƉĂŶĚƚĞƐƚƌŝƐĞƌ͕ĚĞǁĂƚĞƌĐĞůůĂƌĂƐŶĞĞĚĞĚ͘ ϯ͘ ƌŝůůϭϯͲϭͬϮΗŚŽůĞƚŽƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐƉŽŝŶƚĂƐƉĞƌƚŚĞĚŝƌĞĐƚŝŽŶĂůƉůĂŶ͕ǁŝƚŚ^ƉƵĚDƵĚ͘;>tWƌŽŐƌĂŵ͗'ZͬZ^ͬ'tͿ͘ ϰ͘ ZƵŶĂŶĚĐĞŵĞŶƚϭϬͲϯͬϰΗƐƵƌĨĂĐĞĐĂƐŝŶŐƚŽƐƵƌĨĂĐĞ͘ZĞƐƵůƚƐŽĨƚŚĞĐĞŵĞŶƚŽƉĞƌĂƚŝŽŶǁŝůůďĞƐƵďŵŝƚƚĞĚĂƐƐŽŽŶĂƐƉŽƐƐŝďůĞ͘ ϱ͘ /ŶƐƚĂůůKWǁŝƚŚƚŚĞĨŽůůŽǁŝŶŐĞƋƵŝƉŵĞŶƚͬĐŽŶĨŝŐƵƌĂƚŝŽŶ͗ϭϯͲϱͬϴ͟ĂŶŶƵůĂƌƉƌĞǀĞŶƚĞƌ͕ϳͲϱͬϴΗ&Z͛Ɛ͕ďůŝŶĚƌĂŵĂŶĚϮͲϳͬϴ͟ǆϱ͟ sZ͛Ɛ͘ x ^ĞĞƐĞĐƚŝŽŶϰĨŽƌƌĂŵĐŽŶĨŝŐƵƌĂƚŝŽŶũƵƐƚŝĨŝĐĂƚŝŽŶ͘ ϲ͘ dĞƐƚKWƚŽϮϱϬƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝŚŝŐŚ;ϮϰͲϰϴŚƌ͘ƌĞŐƵůĂƚŽƌǇŶŽƚŝĐĞͿ͘ ϳ͘ WŝĐŬƵƉĂŶĚƌƵŶŝŶŚŽůĞǁŝƚŚϵͲϳͬϴΗĚƌŝůůŝŶŐ,ƚŽĚƌŝůůŝŶƚĞƌ ŵĞĚŝĂƚĞŚŽůĞƐĞĐƚŝŽŶ͘ ϴ͘ ŚĂƌƚĐĂƐŝŶŐƉƌĞƐƐƵƌĞƚĞƐƚƚŽϯϱϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ͘ ϵ͘ ƌŝůůŽƵƚƐŚŽĞƚƌĂĐŬĂŶĚϮϬ͛ŽĨŶĞǁŚŽůĞ͘ ϭϬ͘ WĞƌĨŽƌŵ>Kd͘DŝŶŝŵƵŵ>KdƌĞƋƵŝƌĞĚƚŽĚƌŝůůĂŚĞĂĚŝƐϭϭƉƉŐDt͘ ϭϭ͘ ƌŝůůϵͲϳͬϴΗŚŽůĞƚŽƐĞĐƚŝŽŶd;>tWƌŽŐƌĂŵ͗'ZͬZ^ͬEͬEhͿ ϭϮ͘ ZƵŶϳϱͬϴ͟ĐĂƐŝŶŐĂŶĚĐĞŵĞŶƚƚŽĂŵŝŶŝŵƵŵŽĨϮϱϬ͛dsŽƌϱϬϬ͛DĂďŽǀĞĂŶǇŚǇĚƌŽĐĂƌďŽŶďĞĂƌŝŶŐǌŽŶĞƐ;ĐĞŵĞŶƚŝŶŐ ƐĐŚĞŵĂƚŝĐĂƚƚĂĐŚĞĚͿ͘WƌĞƐƐƵƌĞƚĞƐƚĐĂƐŝŶŐŝĨƉŽƐƐŝďůĞŽŶƉůƵŐďƵŵƉƚŽϯϴϱϬƉƐŝ͘ ϭϯ͘ ŚĂŶŐĞƵƉƉĞƌϳͲϱͬϴΗƐŽůŝĚďŽĚǇƌĂŵƐƚŽϮͲϳͬϴ͟ǆϱ͟sZ͛Ɛ͘dĞƐƚKWƚŽϮϱϬͬϯ͕ϱϬϬƉƐŝ͘;ϮϰͲϰϴŚƌ͘ƌĞŐƵůĂƚŽƌǇŶŽƚŝĐĞͿ͘ ϭϰ͘ WŝĐŬƵƉĂŶĚZ/,ǁŝƚŚϲͲϭͬϮ͟ĚƌŝůůŝŶŐĂƐƐĞŵďůǇ͘>ŽŐƚŽƉŽĨĐĞŵĞŶƚǁŝƚŚƐŽŶŝĐƚŽŽůŝŶƌĞĐŽƌĚĞĚŵŽĚĞ͘ ϭϱ͘ ŚĂƌƚĐĂƐŝŶŐƉƌĞƐƐƵƌĞƚĞƐƚƚŽϯ͕ϴϱϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐŝĨŶŽƚƚĞƐƚĞĚŽŶƉůƵŐďƵŵƉ͘ ϭϲ͘ ƌŝůůŽƵƚƐŚŽĞƚƌĂĐŬĂŶĚϮϬĨĞĞƚŽĨŶĞǁĨŽƌŵĂƚŝŽŶ͘WĞƌĨŽƌŵ&/d͘DŝŶŝŵƵŵĂĐĐĞƉƚĂďůĞŝŶŝƚŝĂůůĞĂŬͲŽĨĨĨŽƌĚƌŝůůŝŶŐĂŚĞĂĚŝƐϭϬ͘ϳ ƉƉŐDt͘ ϭϳ͘ ƌŝůůϲͲϭͬϮΗŚŽƌŝǌŽŶƚĂůŚŽůĞƚŽƐĞĐƚŝŽŶd;>tWƌŽŐƌĂŵ͗'ZͬZ^ͬĞŶͬEĞƵͿ͘ ϭϴ͘ ŝƌĐƵůĂƚĞƚŚĞŚŽůĞĐůĞĂŶĂŶĚWKK,͘ ϭϵ͘ ZƵŶϰͲϭͬϮ͟ůŝŶĞƌƚŽd͕ƐĞƚůŝŶĞƌŚĂŶŐĞƌĂŶĚƉĂĐŬĞƌ͘ ϮϬ͘ ĞŵĞŶƚϰͲϭͬϮ͟ůŝŶĞƌĨƌŽŵdƚŽůŝŶĞƌƚŽƉ͘WKK,>W͘ Ϯϭ͘ WƌĞƐƐƵƌĞƚĞƐƚǁĞůůƚŽϯ͕ϴϱϬƉƐŝ͘ZhƚŽƌƵŶƵƉƉĞƌĐŽŵƉůĞƚŝŽŶ͘ ϮϮ͘ ZƵŶϰͲϭͬϮ͟ƵƉƉĞƌĐŽŵƉůĞƚŝŽŶǁŝƚŚŐůĂƐƐƉůƵŐ͕ƉƌŽĚƵĐƚŝŽŶƉĂĐŬĞƌ͕ĚŽǁŶŚŽůĞŐĂƵŐĞ͕ĂŶĚŐĂƐůŝĨƚŵĂŶĚƌĞůƐ͘^ƉĂĐĞŽƵƚĂŶĚ ůĂŶĚƚƵďŝŶŐŚĂŶŐĞƌ͘ Ϯϯ͘ WƌĞƐƐƵƌĞƚĞƐƚŚĂŶŐĞƌƐĞĂůƐƚŽϱ͕ϬϬϬƉƐŝ͘ Ϯϰ͘ WƌĞƐƐƵƌĞƚĞƐƚĂŐĂŝŶƐƚƚŚĞŐůĂƐƐƉůƵŐƚŽƐĞƚƉƌŽĚƵĐƚŝŽŶƉĂĐŬĞƌ͕ƚĞƐƚƚƵďŝŶŐƚŽϰ͕ϱϱϬƉƐŝ͕ĐŚĂƌƚƚĞƐƚ͘ Ϯϱ͘ ůĞĞĚƚƵďŝŶŐƉƌĞƐƐƵƌĞƚŽϮϮϬϬƉƐŝĂŶĚƚĞƐƚ/ƚŽϯ͕ϴϱϬƉƐŝ͕ĐŚĂƌƚƚĞƐƚ͘ Ϯϲ͘ /ŶƐƚĂůů,WͲWsĂŶĚƚĞƐƚƚŽϭϱϬϬƉƐŝ͘ Ϯϳ͘ EŝƉƉůĞĚŽǁŶKW͘ Ϯϴ͘ /ŶƐƚĂůůƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌĂƐƐĞŵďůǇ͘EͬhƚƌĞĞĂŶĚƚĞƐƚƚŽϭϬ͕ϬϬϬƉƐŝͬϭϬŵŝŶƵƚĞƐ͘ Ϯϵ͘ &ƌĞĞǌĞƉƌŽƚĞĐƚĚŽǁŶƚƵďŝŶŐĂŶĚĂŶŶƵůƵƐ͘ ϯϬ͘ ^ĞĐƵƌĞǁĞůů͘ZŝŐĚŽǁŶĂŶĚŵŽǀĞŽƵƚ͘ WůĞĂƐĞŶŽƚĞʹdŚŝƐǁĞůůǁŝůůďĞĨƌĂĐ͛Ě ϯ^ͲϳϮϭK'ϭϬͲϰϬϭW ϯͬϭϴͬϮϬϮϱ ϯ^ͲϳϮϭK'ϭϬͲϰϬϭWϱͮϭϯ ϰ͘ KWĂŶĚŝǀĞƌƚĞƌ/ŶĨŽƌŵĂƚŝŽŶ ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϯΘϳͿ WůĞĂƐĞƌĞĨĞƌĞŶĐĞKWĂŶĚĚŝǀĞƌƚĞƌƐĐŚĞŵĂƚŝĐƐŽŶĨŝůĞĨŽƌŽǇŽŶϮϱ ŽǇŽŶϮϱǁŝůůƵƐĞĂKWƐƚĂĐŬĞƋƵŝƉƉĞĚǁŝƚŚĂŶĂŶŶƵůĂƌƉƌĞǀĞŶƚĞƌ͕ĨŝǆĞĚ͕ϳͲϱͬϴΗƐŽůŝĚďŽĚǇƌĂŵƐ͕ ďůŝŶĚͬƐŚĞĂƌƌĂŵƐĂŶĚǀĂƌŝĂďůĞďŽƌĞƌĂŵƐǁŚŝůĞĚƌŝůůŝŶŐĂŶĚƌƵŶŶŝŶŐĐĂƐŝŶŐŝŶƚŚĞŝŶƚĞƌŵĞĚŝĂƚĞƐĞĐƚŝŽŶŽĨ ϯ^ͲϳϮϭ͘ ϯ^ͲϳϮϭŚĂƐĂD^WŽĨϭϰϱϲƉƐŝŝŶƚŚĞŝŶƚĞƌŵĞĚŝĂƚĞŚŽůĞƐĞĐƚŝŽŶƵƐŝŶŐƚŚĞŵĞƚŚŽĚŽůŽŐǇƉƌĞƐĞŶƚĞĚŝŶ ƐĞĐƚŝŽŶϱD^WĐĂůĐƵůĂƚŝŽŶƐ͘tŝƚŚĂD^WůĞƐƐƚŚĂŶϯϬϬϬƉƐŝŽŶ ŽĐŽWŚŝůůŝƉƐĐůĂƐƐŝĨŝĞƐƚŚĞŽƉĞƌĂƚŝŽŶĂƐĂ ůĂƐƐϮ͘ WĞƌϮϬϮϱ͘Ϭϯϱ͘Ğ͘ϭ͗͘ &ŽƌĂŶŽƉĞƌĂƚŝŽŶǁŝƚŚĂŵĂǆŝŵƵŵƉŽƚĞŶƚŝĂůƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞŽĨϯ͕ϬϬϬƉƐŝŽƌůĞƐƐ͕KWŵƵƐƚŚĂǀĞĂƚůĞĂƐƚ ƚŚƌĞĞƉƌĞǀĞŶƚĞƌƐ͕ŝŶĐůƵĚŝŶŐ͗ ŝ͘ KŶĞĞƋƵŝƉƉĞĚǁŝƚŚƉŝƉĞƌĂŵƐƚŚĂƚĨŝƚƚŚĞƐŝǌĞŽĨĚƌŝůůƉŝƉĞ͕ƚƵ ďŝŶŐŽƌĐĂƐŝŶŐďĞŐŝŶƵƐĞĚ͕ĞǆĐĞƉƚƚŚĂƚƉŝƉĞƌĂŵƐ ŶĞĞĚŶŽƚďĞƐŝǌĞĚƚŽďŽƚƚŽŵͲŚŽůĞĂƐƐĞŵďůŝĞƐĂŶĚĚƌŝůůĐŽůůĂƌƐ͘ ŝŝ͘ KŶĞǁŝƚŚďůŝŶĚƌĂŵƐ ŝŝŝ͘ KŶĞĂŶŶƵůĂƌƚǇƉĞ /ŶƚĞƌŵĞĚŝĂƚĞƌŝůůŝŶŐͬĂƐŝŶŐ x ŶŶƵůĂƌWƌĞǀĞŶƚĞƌ;ŝŝŝͿ x ϳͲϱͬϴΗ&ŝǆĞĚZĂŵƐ x ůŝŶĚͬ^ŚĞĂƌZĂŵƐ;ŝŝͿ x sZ͛Ɛ;ŝͿ WƌŽĚƵĐƚŝŽŶ͗ x ŶŶƵůĂƌWƌĞǀĞŶƚĞƌ;ŝŝŝͿ x sZ͛Ɛ;ŝͿ x ůŝŶĚͬ^ŚĞĂƌZĂŵƐ;ŝŝͿ x sZ͛Ɛ;ŝͿ /ƚŝƐƌĞƋƵĞƐƚĞĚƚŚĂƚĂǀĂƌŝĂŶĐĞŽĨƚŚĞĚŝǀĞƌƚĞƌƌĞƋƵŝƌĞŵĞŶƚƵŶĚĞƌϮϬϮϱ͘Ϭϯϱ;ŚͿ;ϮͿŝƐŐƌĂŶƚĞĚ͘ƚϯ^͕ ƚŚĞƌĞŚĂƐŶŽƚďĞĞŶƐŝŐŶŝĨŝĐĂŶƚŝŶĚŝĐĂƚŝŽŶŽĨƐŚĂůůŽǁŐĂƐŽƌŐĂƐŚǇĚƌĂƚĞƐƚŚƌŽƵŐŚƚŚĞƐƵƌĨĂĐĞŚŽůĞŝŶƚĞƌǀĂů͘ dŚĞƌĞĂƌĞϵƉƌĞǀŝŽƵƐůǇĚƌŝůůĞĚǁĞůůƐ;ϯ^ͲϲϬϲ͕ϯ^ͲϲϭϬ͕ϯ^Ͳϲϭϭ͕ϯ^ͲϲϭϮ͕ϯ^Ͳϲϭϳ͕ϯ^ͲϲϮϰ͕ϯ^ͲϲϮϲ͕ϯ^Ͳϳϭϰ͕ϯ^Ͳ ϯ^ͲϳϮϭK'ϭϬͲϰϬϭW ϯͬϭϴͬϮϬϮϱ ϯ^ͲϳϮϭK'ϭϬͲϰϬϭWϲͮϭϯ ϲϬϮͿǁŝƚŚŝŶϱϬϬ͛ŽĨƚŚĞƉƌŽƉŽƐĞĚϯ^ͲϳϮϭƐƵƌĨĂĐĞƐŚŽĞůŽĐĂƚŝŽŶ͘EŽŶĞŽĨƚŚĞƐĞǁĞůůƐĞŶĐŽƵŶƚĞƌĞĚĂŶǇ ƐŝŐŶŝĨŝĐĂŶƚŝŶĚŝĐĂƚŝŽŶŽĨƐŚĂůůŽǁŐĂƐŽƌŐĂƐŚǇĚƌĂƚĞƐ͘ 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&ϭϯͲϭͬϮΗ ϮϬΗ ϭϮϬ ϭϮϬ ϭϯ͘Ϯ ϴ͘ϴ ϱϱ ϯϬϰϴ ϮϱϮϱ ϴ͘ϴ ϭ͕ϭϱϱ ϳϬϳϬ ϵϬϯ /EdϭϵͲϳͬϴΗ ϭϬͲϯͬϰΗ ϯϬϰϴ ϮϱϮϱ ϭϯ͘Ϯ ϴ͘ϴ ϭ͕ϭϱϱ ϭϬϬϱϯ ϰϬϳϮ ϴ͘ϴ ϭ͕ϴϲϯ ϭ͕ϰϱϲ ϭ͕ϰϴϭϭ͕ϰϱϲ WZKϲͲϭͬϮΗ ϳͲϱͬϴΗ ϭϬϬϱϯ ϰϬϳϮ ϭϯ͘ϴ ϴ͘ϴ ϭ͕ϴϲϯ ϮϬϲϳϭ ϰϮϬϱ ϴ͘ϴ ϭ͕ϵϮϰ ϭ͕ϱϬϰ Ϯ͕ϱϭϱϭ͕ϱϬϰ ΎDĂǆŝŵƵŵƉŽƚĞŶƚŝĂůƉŽƌĞƉƌĞƐƐƵƌĞŝŶƚŚĞ^ƵƐŝƚŶĂ^ĂŶĚŝĨƉƌĞƐĞŶƚ ;ͿĚĂƚĂŽŶƉŽƚĞŶƚŝĂůŐĂƐǌŽŶĞƐ͖ dŚĞƉůĂŶŶĞĚǁĞůůďŽƌĞŝƐŶŽƚĞǆƉĞĐƚĞĚƚŽƉĞŶĞƚƌĂƚĞĂŶǇƐŚĂůůŽǁŐĂƐǌŽŶĞƐ͘ ;ͿĚĂƚĂĐŽŶĐĞƌŶŝŶŐƉŽƚĞŶƚŝĂůĐĂƵƐĞƐŽĨŚŽůĞƉƌŽďůĞŵƐƐƵĐŚĂƐĂďŶŽƌŵĂůůǇŐĞŽͲƉƌĞƐƐƵƌĞĚƐƚƌĂƚĂ͕ůŽƐƚ ĐŝƌĐƵůĂƚŝŽŶǌŽŶĞƐ͕ĂŶĚǌŽŶĞƐƚŚĂƚŚĂǀĞĂƉƌŽƉĞŶƐŝƚǇĨŽƌĚŝĨĨĞƌĞŶƚŝĂůƐƚŝĐŬŝŶŐ͖ WůĞĂƐĞƐĞĞƌŝůůŝŶŐ,ĂǌĂƌĚƐ^ƵŵŵĂƌǇ ϯ^ͲϳϮϭK'ϭϬͲϰϬϭW ϯͬϭϴͬϮϬϮϱ ϯ^ͲϳϮϭK'ϭϬͲϰϬϭWϳͮϭϯ 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 ϭϬͲϯͬϰΗ ϭϯͲϭͬϮΗ ϰϱ͘ϱη >ϴϬ ,ϱϲϯ ĞŵĞŶƚƚŽ^ƵƌĨĂĐĞ ϳͲϱͬϴΗ ϵͲϳͬϴΗ Ϯϵ͘ϳη ϯϯ͘ϳη >ϴϬ WϭϭϬ^,ϱϲϯϮϱϬ͛dsŽƌϱϬϬ͛D͕ǁŚŝĐŚĞǀĞƌŝƐŐƌĞĂƚĞƌ͕ĂďŽǀĞ ŚŝŐŚĞƐƚƐŝŐŶŝĨŝĐĂŶƚŚǇĚƌŽĐĂƌďŽŶďĞĂƌŝŶŐǌŽŶĞ ϰͲϭͬϮΗ ϲͲϭͬϮΗ ϭϮ͘ϲη WϭϭϬͲ^ ,ϱϲϯ ĞŵĞŶƚƚŽůŝŶĞƌƚŽƉ͘ ϭϬͲϯͬϰΗ^ƵƌĨĂĐĞĂƐŝŶŐƌƵŶƚŽϯϬϰϴΖDͬϮϱϮϱΖdsĞŵĞŶƚWůĂŶ͗ ĞŵĞŶƚĨƌŽŵϯϬϰϴ͛DƚŽϮϱϰϴ͛;ϱϬϬ͛ŽĨƚĂŝůͿǁŝƚŚůĂƐƐ'нĚĚƐΛϭϱ͘ϴƉƉŐ͕ĂŶĚĨƌŽŵϮϱϰϴΖƚŽƐƵƌĨĂĐĞ ǁŝƚŚϭϭ͘ϬƉƉŐĞĞƉZd͘ƐƐƵŵĞϮϬϬйĞǆĐĞƐƐĂŶŶƵůĂƌǀŽůƵŵĞŝŶƉĞƌŵĂĨƌŽƐƚĂŶĚϱϬйĞǆĐĞƐƐďĞůŽǁƚŚĞ ƉĞƌŵĂĨƌŽƐƚ;ϭϳϱϰ͛DͿ͕ǌĞƌŽĞǆĐĞƐƐŝŶϮϬ͟ĐŽŶĚƵĐƚŽƌ͘ >ĞĂĚϰϭϵďďůƐсхϭϮϮϲƐǆŽĨϭϭ͘ϬƉƉŐĞĞƉZdнĚĚΖƐΛϭ͘ϵϮĨƚϹͬƐŬ dĂŝůϱϲďďůƐсхϮϳϮƐǆŽĨϭϱ͘ϴƉƉŐůĂƐƐ'нĚĚΖƐΛϭ͘ϭϲĨƚϹͬƐŬ ϳͲϱͬϴΗ/ŶƚĞƌŵĞĚŝĂƚĞĂƐŝŶŐƌƵŶƚŽϭϬϬϱϯΖDͬϰϬϳϮΖdsĞŵĞŶƚWůĂŶ͗ WƌŝŵĂƌǇĐĞŵĞŶƚũŽďĐŽŶƐŝƐƚƐŽĨĂϭϱ͘ϯƉƉŐƐůƵƌƌǇĚĞƐŝŐŶĞĚƚŽďĞĂƚϴϰϲϬ͛D͕ǁŚŝĐŚŝƐϮϱϬΖdsĂďŽǀĞƚŚĞ ƉƌŽŐŶŽƐĞĚƐŚĂůůŽǁĞƐƚŚǇĚƌŽĐĂƌďŽŶďĞĂƌŝŶŐǌŽŶĞdŽƉŽǇŽƚĞ͕<ϯ͘/ĨĂƐŚĂůůŽǁĞƌŚǇĚƌŽĐĂƌďŽŶǌŽŶĞŽĨ ƉƌŽĚƵĐŝďůĞǀŽůƵŵĞƐ͕ŝƐĞŶĐŽƵŶƚĞƌĞĚǁŚŝůĞĚƌŝůůŝŶŐ͕ĂůŽŶŐĞƌƉƌŝŵĂƌǇũŽďŽƌĂϮŶĚƐƚĂŐĞĐĞŵĞŶƚũŽďǁŝůůďĞ ƉĞƌĨŽƌŵĞĚƚŽŝƐŽůĂƚĞƚŚŝƐǌŽŶĞ͘ƐƐƵŵĞϰϬйĞǆĐĞƐƐĂŶŶƵůĂƌǀŽůƵŵĞ͘ dĂŝůϴϵďďůƐсхϰϬϬƐǆŽĨϭϱ͘ϯƉƉŐůĂƐƐ'нĚĚΖƐΛϭ͘ϮϰϲĨƚϹͬƐŬ ϰͲϭͬϮΗWƌŽĚƵĐƚŝŽŶ>ŝŶĞƌƌƵŶƚŽϮϬϲϳϭΖDͬϰϮϬϱΖdsĞŵĞŶƚWůĂŶ͗ WƌŝŵĂƌǇĐĞŵĞŶƚũŽďĐŽŶƐŝƐƚƐŽĨĂϭϱ͘ϯƉƉŐƐůƵƌƌǇĚĞƐŝŐŶĞĚƚŽďĞĂƚϵϴϳϴΖDͬϰϬϰϲΖds͕ǁŚŝĐŚŝƐĂƚƚŚĞ ůŝŶĞƌƚŽƉ͘ dĂŝůϮϳϵďďůƐсхϭϮϱϭƐǆŽĨϭϱ͘ϯƉƉŐůĂƐƐ'нĚĚΖƐнĚĚΖƐΛϭ͘ϮϱĨƚϹͬƐŬ ϯ^ͲϳϮϭK'ϭϬͲϰϬϭW ϯͬϭϴͬϮϬϮϱ ϯ^ͲϳϮϭK'ϭϬͲϰϬϭWϴͮϭϯ ϴ͘ ƌŝůůŝŶŐ&ůƵŝĚWƌŽŐƌĂŵ ;ZĞƋƵŝƌĞŵĞŶƚƐŽĨϮϬϮϱ͘ϬϬϱ;ĐͿ;ϴͿͿ ^ƵƌĨĂĐĞ/ŶƚĞƌŵĞĚŝĂƚĞWƌŽĚƵĐƚŝŽŶ ,ŽůĞ^ŝǌĞŝŶϭϯͲϭͬϮΗ ϵͲϳͬϴΗϲͲϭͬϮΗ ĂƐŝŶŐ^ŝǌĞŝŶϭϬͲϯͬϰΗϳͲϱͬϴΗϰͲϭͬϮΗ ĞŶƐŝƚǇƉƉŐϴ͘ϲͲϵ͘ϲƉƉŐ ϵ͘ϬͲϭϬ͘ϬƉƉŐ ϵ͘ϬͲϭϬ͘ϬƉƉŐ WsĐW>W ϭϬͲϯϬ ϭϬͲϯϬ zWůďͬ͘ϭϬϬĨƚϮϯϱͲϱϬ ϴͲϭϲ ϴͲϭϲ &ƵŶŶĞůsŝƐĐŽƐŝƚǇƐͬƋƚϭϱϬͲϯϬϬ ϰϬͲϲϱ ϰϬͲϲϱ /ŶŝƚŝĂů'ĞůƐůďͬ͘ϭϬϬĨƚϮϱϬ Eͬ Eͬ ϭϬDŝŶƵƚĞ'ĞůƐůďͬ͘ϭϬϬĨƚϮϲϬ Eͬ Eͬ W/&ůƵŝĚ>ŽƐƐĐĐͬϯϬŵŝŶфϰϱ Eͬ Eͬ ,W,d&ůƵŝĚ>ŽƐƐĐĐͬϯϬŵŝŶŶͬĂ фϰ фϰ Ɖ,ϴ͘ϱͲϵ͘ϱ ϵ͘ϱʹϭϬ͘Ϭ ϵ͘ϱͲϭϬ͘Ϭ KŝůͬtĂƚĞƌZĂƚŝŽEͬ ϲϱͬϯϱʹϳϬͬϯϬ ϲϱͬϯϱʹϳϬͬϯϬ ^ƵƌĨĂĐĞ,ŽůĞ͗ ĨƌĞƐŚǁĂƚĞƌ^ƉƵĚDƵĚǁŝůůďĞƵƐĞĚĨŽƌƚŚĞƐƵƌĨĂĐĞŝŶƚĞƌǀĂů͘<ĞĞƉĨůŽǁůŝŶĞǀŝƐĐŽƐŝƚǇĂƚцϮϬϬƐĞĐͬƋƚǁŚŝůĞ ĚƌŝůůŝŶŐĂŶĚƌƵŶŶŝŶŐĐĂƐŝŶŐ͘ZĞĚƵĐĞǀŝƐĐŽƐŝƚǇƉƌŝŽƌƚŽĐĞŵĞŶƚŝŶŐ͘DĂŝŶƚĂŝŶŵƵĚǁĞŝŐŚƚчϭϬ͘ϬƉƉŐďǇƵƐĞŽĨ ƐŽůŝĚƐĐŽŶƚƌŽůƐǇƐƚĞŵĂŶĚĚŝůƵƚŝŽŶƐǁŚĞƌĞŶĞĐĞƐƐĂƌǇ͘ /ŶƚĞƌŵĞĚŝĂƚĞ͗ E&ƐǇƐƚĞŵǁŝůůďĞƵƐĞĚ͘ŶƐƵƌĞŐŽŽĚŚŽůĞĐůĞĂŶŝŶŐďǇƉƵŵƉŝŶŐƌĞŐƵůĂƌƐǁĞĞƉƐĂŶĚŵĂǆŝŵŝǌŝŶŐĨůƵŝĚ ĂŶŶƵůĂƌǀĞůŽĐŝƚǇ͘DĂŝŶƚĂŝŶŵƵĚǁĞŝŐŚƚĨƌŽŵϵ͘ϬͲϭϬ͘ϬƉƉŐĂŶĚďĞƉƌĞƉĂƌĞĚƚŽĂĚĚůŽƐƐĐŝƌĐƵůĂƚŝŽŶƐ ŵĂƚĞƌŝĂůƐĂƐŶĞĞĚĞĚ͘ WƌŽĚƵĐƚŝŽŶ,ŽůĞ͗ dŚĞŚŽƌŝǌŽŶƚĂůƉƌŽĚƵĐƚŝŽŶŝŶƚĞƌǀĂůǁŝůůďĞĚƌŝůůĞĚǁŝƚŚE&ƐǇƐ 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ƌĞĂŽĨZĞǀŝĞǁ ϯ^ͲϳϮϭƌĞĂŽĨZĞǀŝĞǁ;KZͿ ŶƌĞĂŽĨZĞǀŝĞǁƉůŽƚŝƐƐŚŽǁŶďĞůŽǁŽĨƚŚĞϯ^ͲϳϮϭŝŶũĞĐƚŽƌƉůĂŶŶĞĚǁĞůůƉĂƚŚĂŶĚŽĨĨƐĞƚǁĞůůƐ͘dŚĞƌĞĂƌĞ ǌĞƌŽǁĞůůƐǁŝƚŚŝŶŝŶƚŚĞƋƵĂƌƚĞƌŵŝůĞƌĞǀŝĞǁĨŽƌϯ^ͲϳϮϭ͘ 40 500 500 800 800 1000 1000 1500 1500 2000 2000 2500 2500 3000 3000 4000 4000 7000 7000 1200 1200 22000 3S-721 (I03) wp04 Plan Summary 3S-721 (I03) wp04 3S-734 (P04) wp04 3S-714 3S-723 wp06 3S-24 3S-24A 3S-24B 3S-613 3S-611 3S-611PB1 3S-21 3S-735 (P11) wp03 3S-26 PALM 1 3S-22 3S-719 (P02) wp05 3S-624 3S-740 (I15) wp03 3S-722 3S-16 3S-736 (I04) wp03 3S-718 3S-17A 3S-19 3S-730 (P10) wp04 3S-612 3S-610 3S-617 3S-626 3S-15 3S-17 3S-741 (P15) wp02 3S-732 (I10) wp05 3S-620 3S-23A 3S-23 3S-738 (I05) wp05 3S-18 3S-14 3S-615 3S-10 3S-737 (P05) wp03 3S-625 3T-730 wp08.1 3T-731 wp09.1 3S-714 0 4 Dogleg Severity0 3000 6000 9000 12000 15000 18000 21000 Measured Depth 10-3/4" Surface Casing 7-5/8" 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] 3S-723 wp06 3S-243S-24A3S-24B 3S-21 3S-727 (P23A) wp03 3S-729 (I22A) wp03 3S-26 PALM 1 3S-22 3S-719 (P02) wp05 3S-624 3S-722 3S-16 3S-718 3S-17A 3S-728 (I09) wp04 3S-19 3S-730 (P10) wp04 3S-617 3S-626 3S-626PB1 3S-17 3S-620 3S-23A 3S-23 3S-18 3S-625 0 4500 True Vertical Depth0 2500 5000 7500 10000 12500 15000 Vertical Section at 212.63° 10-3/4" Surface Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 0 28 55 Centre to Centre Separation0 2750 5500 8250 11000 13750 16500 19250 Measured Depth Equivalent Magnetic Distance DDI 7.372 SURVEY PROGRAM Date: 2019-05-03T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 40.00 1600.00 3S-721 (I03) wp04 (3S-721 (I03)) r.5 SDI_URSA1 1600.00 2969.11 3S-721 (I03) wp04 (3S-721 (I03))MWD+IFR2+SAG+MS2969.11 10052.57 3S-721 (I03) wp04 (3S-721 (I03))MWD+IFR2+SAG+MS10052.57 20671.02 3S-721 (I03) wp04 (3S-721 (I03))MWD+IFR2+SAG+MS Surface Location North / 5993616.79 East / 1616089.07 Ground / 24.80 CASING DETAILS TVD MD Name 2493.00 2969.11 10-3/4" Surface Casing 4072.00 10052.57 7-5/8" Intermediate Casing 4204.80 20671.00 4-1/2" Production Liner Mag Model & Date:BGGM2024 01-Apr-25 Magnetic North is 13.80° East of True North (Magnetic Declination) Mag Dip & Field Strength:80.60°57178.10nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.25 3 600.00 3.75 285.00 599.79 2.54 -9.48 1.25 285.00 2.97 Start Build 2.50 4 900.00 11.25 285.00 897.01 12.67 -47.28 2.50 0.00 14.82 Start DLS 2.50 TFO -12.00 5 1596.94 28.52 277.51 1550.00 52.31 -279.69 2.50 -12.00 106.76 Start 113.81 hold at 1596.94 MD 6 1710.75 28.52 277.51 1650.00 59.41 -333.57 0.00 0.00 129.83 Start DLS 3.00 TFO -15.00 7 2986.26 66.16 267.42 2500.00 73.42 -1252.62 3.00 -15.00 613.60 Start 20.00 hold at 2986.26 MD 8 3006.26 66.16 267.42 2508.08 72.60 -1270.89 0.00 0.00 624.15 Start 1000.00 hold at 3006.26 MD 9 4006.26 66.16 267.42 2912.33 31.35 -2184.61 0.00 0.00 1151.57 Start DLS 1.00 TFO 30.84 10 5745.03 81.31 276.33 3398.88 90.73 -3845.92 1.00 30.84 1997.37 Start 2603.84 hold at 5745.03 MD 11 8348.87 81.31 276.33 3792.32 374.61 -6404.16 0.00 0.00 3137.73 Start DLS 3.50 TFO -94.75 12 11226.67 87.00 175.00 4194.33 -1375.85 -8173.68 3.50 -94.75 5566.06 Start 200.00 hold at 11226.67 MD 13 11426.67 87.00 175.00 4204.80 -1574.82 -8156.27 0.00 0.00 5724.24 Start 20.00 hold at 11426.67 MD 14 11446.67 87.00 175.00 4205.85 -1594.72 -8154.53 0.00 0.00 5740.06 Start DLS 1.50 TFO -41.46 15 11754.97 90.47 171.94 4212.66 -1900.86 -8119.48 1.50 -41.46 5978.98 Start 3998.10 hold at 11754.97 MD 16 15753.08 90.47 171.94 4179.99 -5859.33 -7558.91 0.00 0.00 9010.41 Start DLS 1.00 TFO 179.96 17 15799.89 90.00 171.94 4179.80 -5905.68 -7552.34 1.00 179.96 9045.91 Start DLS 1.00 TFO 178.71 18 15829.39 89.71 171.95 4179.88 -5934.90 -7548.21 1.00 178.71 9068.28 Start 4841.62 hold at 15829.39 MD 19 20671.02 89.71 171.95 4204.80 -10728.71 -6869.93 0.00 0.00 12739.75 TD at 20671.02 FORMATION TOP DETAILS TVDPath Formation 1411.80 Top Ugnu 1664.80 Base Permafrost 2008.80 Top West Sak 2425.80 Base West Sak 2656.80 Campanian Sand (C-80) 3333.80 C-50 3911.80 C-35 4156.80 Top Coyote (Top Nanushuk), K3 Plan 40+24.8 @ 64.80usft (Doyon 25) Project: Kuparuk River Unit_2Site: Kuparuk 3S PadWell: Plan: 3S-721 (I03)Wellbore: 3S-721 (I03)Design: 3S-721 (I03) wp04-10000-50000South(-)/North(+) (2500 usft/in)-15000 -10000 -5000 0 5000West(-)/East(+) (2500 usft/in)3S-721 T31320 ft3S-721 I03 T3 0328243S-721 I03 T2 0328243S-721 T1 1320 ft3S-721 I03 T1 0328243S-734 (P04) wp043S-723 wp063S-243S-24A3S-24B3S-6133S-6113S-611PB13S-213S-727 (P23A) wp033S-729 (I22A) wp033S-731 (P07) wp043S-735 (P11) wp033 S -2 6 PALM 13 S -2 2 3S-719 (P02) wp053S-6243S-740 (I15) wp033S-7223S -163S-736 (I04) wp033S-7183 S -1 7 A3S-728 (I09) wp043S-193S-730 (P10) wp043S-6123S-6103S-6173S-6263S-626PB13S-733 (I07) wp043S-153S-173S-741 (P15) wp023S-732 (I10) wp053S-6203S-23A3 S -2 3 3S-738 (I05) wp053S-183S-143S-6153S-103S-737 (P05) wp033S-6253T-730 wp08.13T-731 wp09.13S-7145001000150020002500 3000 35004 0 0 0 42053S-721 (I03) wp04Plan View with Offset Wells Project: Kuparuk River Unit_2Site: Kuparuk 3S PadWell: Plan: 3S-721 (I03)Wellbore: 3S-721 (I03)Design: 3S-721 (I03) wp04-10000-50000South(-)/North(+) (2500 usft/in)-15000 -10000 -5000 0 5000West(-)/East(+) (2500 usft/in)3S-721 T31320 ft3S-721 I03 T3 0328243S-721 I03 T2 0328243S-721 T1 1320 ft3S-721 I03 T1 0328245001000150020002500 3000 35004 0 0 0 42053S-721 (I03) wp04Plan View 019003800True Vertical Depth (950 usft/in)0 4000 8000 12000 16000Vertical Section at 212.63° (2000 usft/in)100020003000400050006000700080009000100001100012000 13000 14000 150001600017000180001900020000Plan: 3S-721 (I03)/3S-721 (I03) wp04Start Build 1.25Start Build 2.50Start DLS 2.50 TFO -12.00Start 113.81 hold at 1596.94 MDStart DLS 3.00 TFO -15.00Start 20.00 hold at 2986.26 MDStart 1000.00 hold at 3006.26 MDStart DLS 1.00 TFO 30.84Start 2603.84 hold at 5745.03 MDStart DLS 3.50 TFO -94.75Start 200.00 hold at 11226.67 MDStart 20.00 hold at 11426.67 MDStart DLS 1.50 TFO -41.46Start 3998.10 hold at 11754.97 MDStart DLS 1.00 TFO 179.96Start DLS 1.00 TFO 178.71Start 4841.62 hold at 15829.39 MDTD at 20671.02Section View Project: Kuparuk River Unit_2Site: Kuparuk 3S PadWell: Plan: 3S-721 (I03)Wellbore: 3S-721 (I03)Design: 3S-721 (I03) wp04 !! 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B $ 8/ -2 * &@C 1/ ,C < & 4** + - 4** + * + - $%$&' ( )$&'* + , 1 / -2 ? ; * ? 3 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. COYOTE OILKUPARUK RIVER KRU 3S-721 225-025 WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 3S-721Initial Class/TypeSER / PENDGeoArea890Unit11160On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2250250KUPARUK RIVER, COYOTE OIL - 490120NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA1Permit fee attachedYesADL380107, ADL025544 , and ADL0255512Lease number appropriateYes3Unique well name and numberYesKUPARUK RIVER, COYOTE OIL - 490120 - governed by CO 6184Well 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 forceNo11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitYesArea Injection Order No. 4514Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYes15All wells within 1/4 mile area of review identified (For service well only)No16Pre-produced injector: duration of pre-production less than 3 months (For service well only)Yes92"18Conductor string providedYes3048' MD19Surface casing protects all known USDWsYes141% excess20CMT vol adequate to circulate on conductor & surf csgYes21CMT vol adequate to tie-in long string to surf csgYes22CMT 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 approvedYes26Adequate wellbore separation proposedYesDiverter variance granted per 20 AAC 25.035(h)(2)27If diverter required, does it meet regulationsYesMax reservoir pressure is 1924 psig(8.8 ppg EMW); will drill w/ 9-10 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 1504 psig; will test BOPs initially to 5000 psig and subsuquently to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownNo33Is presence of H2S gas probableYes34Mechanical condition of wells within AOR verified (For service well only)Yes35Permit can be issued w/o hydrogen sulfide measuresYesExpected reservoir pressure is 8.8 ppg EMW.36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprADDDate4/10/2025ApprVTLDate4/10/2025ApprADDDate4/9/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 4/10/2025