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224-094
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3T-608 KUPARUK RIV UNIT 3T-608 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/10/2025 3T-608 50-103-20890-00-00 224-094-0 W SPT 4981 2240940 1500 167 169 168 169 520 580 580 580 INITAL P Kam StJohn 4/22/2025 Initial MIT-IA for new injector 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 3T-608 Inspection Date: Tubing OA Packer Depth 920 2005 1970 1965IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS250422131856 BBL Pumped:1.3 BBL Returned:1.3 Tuesday, June 10, 2025 Page 1 of 1 9 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.06.10 15:33:05 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ ConocoPhillips Alaska, Inc. Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 21206 feet feet true vertical 5063 feet feet Effective Depth measured 21206 feet 9816 / 9952 feet true vertical 5063 feet 4981 / 5008 feet Perforation depth Measured depth NA feet True Vertical depth NA feet Tubing (size, grade, measured and true vertical depth)4.5" 12.6# L80 9958' MD 5010' TVD Baker ZXP 9952' MD 5008' TVD Packers and SSSV (type, measured and true vertical depth)HAL TNT 9816' MD 4981' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Torok Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Kirsty Glasheen 3/11/2025 Contact Name:Kirsty Glasheen Contact Email:Kirsty.Glasheen@ConocoPhillips.com Authorized Title:Completions Engineer Contact Phone:907-350-4310 2427 Burst Collapse 2470 measured TVD Intermediate Liner 9109 973 11254 Casing Structural 4812 5038 4-1/2" 9147 10120 21206 5063 Plugs Junk measured 3,823,270 lbs 16/20 WanLi Light weight ceramic proppant, 72,000 lbs of 100 Mesh, and 3257 psi avg treating pressure/4996 psi avg BHG pressure. Length 81 2549 119Conductor Surface Intermediate 20" 10-3/4" Job logs attached 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL025528 / ADL 393883 Kuparuk Field / Torok Oil Pool KRU 3T-608 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 224-094 50-103-20890-00-00 P.O. Box 100360 Anchorage, AK 99510-03603. Address: 7-5/8" 11590 7-5/8" 4790 7850 6890 10860 TBD N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf MD 10,485' MD to 20,989' MD Size 119 52102587 324-661 Sr Pet Eng: 9210 Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:47 am, Mar 12, 2025 CDW 03/12/2025 DSR-3/24/25VTL 4/22/2025 Sales Order# Prepared By: William Martin Gregory Koester Nannook Crew 909746254 Intervals 1-12 Moraine Notice:Althoughtheinformationcontainedinthisreportisbasedonsoundengineeringpractices,thecopyright owner(s)does(do)notacceptanyresponsibilitywhatsoever,innegligenceorotherwise,foranylossordamage arisingfromthepossessionoruseofthereportwhetherintermsofcorrectnessorotherwise.Theapplication, therefore,bytheuserofthisreportoranypartthereof,issolelyattheuser’sownrisk. 3T-608 Conoco Phillips Harrison Bay County, AK Post Job Report Stimulation Treatment API: 50-103-20889 Prepared for: Manabu Nozaki December 16, 2024 Moraine Formation 30# Hybor G Hybrid Table of Contents Section Page(s) ExecutiveSummary ActualDesign WellboreInformation IntervalSummary FluidSystemͲProppantSummary Interval1Plots Interval2Plots Interval3Plots Interval4Plots Interval5Plots Interval7Plots Interval8Plots Interval9Plots Interval10Plots Interval11Plots Interval12Plots Appendix WellSummary ChemicalSummary PlannedDesign WaterStraps12.9 WaterStraps12.10 WaterStraps12.11 WaterStraps12.15 WaterAnalysis12.9 WaterAnalysis12.10 WaterAnalysis12.11 WaterAnalysis12.5 RealͲTimeQC EventLog12.9 EventLog12.10 EventLog12.11 EventLog12.15 PrejobBreakTest Zone1 Zone2 Zone3 Zone4 Zone5 Zone7 Zone8 Zone9 Zone10 Zone11 Zone12 SandSieveAnalysis 126 127 128 121 122 123 124 125 116 117 118 119 120 111 112Ͳ113 113 114 115 106 107 108 109 110 98 99Ͳ102 103 104 105 13Ͳ21 22 23Ͳ33 35Ͳ41 3 4Ͳ7 8 97 65Ͳ68 96 42Ͳ45 46Ͳ53 54Ͳ64 69Ͳ72 73Ͳ76 77Ͳ80 81Ͳ91 92Ͳ95 ConocoPhillipsͲ3TͲ608 TOC 2 104,899 gallons of 30# Linear 10,440 gallons of Freeze Protect 840,112 gallons of 30# Hybor G-i 2,200,000 pounds of Wanli 16/20 Ceramic 44,000 pounds of 100M 100,692 gallons of 30# Linear 11,022 gallons of Freeze Protect 871,314 gallons of 30# Hybor G-i 2,271,907 pounds of Wanli 16/20 Ceramic 48,000 pounds of 100M Thank you, William Martin Senior Technical Professional Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. EngineeringExecutiveSummary On December 09, 2024 a stimulation treatment was performed in the Moraine formation on the 3T-608 well in Harrison Bay County, AK. The 3T-608 was a 22 stage Horizontal Sleeve Design. The first 12 of which were pumped on this first visit. The proposed treatment for the first 12 intervals consisted of: The actual treatment fully completed 11 of 22 stages. 1 stage was skipped, 0 stage screened out and 0 stages were cut short of design. The actual treatment consisted of: A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided to summarize events and changes to the proposed treatment: The Treatment for 3T-608 was split into the toe completion and the heel completion. For the toe completion the first 12 intervals, minus interval 6 which was skipped for formation reasons, will be hydraulically fractured and flow tested before returning to hydraulically fracture the heel. For the toe completion, all intervals except the intentionally skipped interval 6 were pumped to completion without design changes. Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids. No mid job design changes were made to the fluid system. Raw MO-67 was pumped at a set point of 0.25 gal/Mgal. ConocoPhillipsͲ3TͲ608 ExecutiveSummary 3 CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDE BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6PropCum. Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) lb 1Ͳ1 ShutͲIn ShutͲIn Ͳ 1Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,500 1,500 36 36 1Ͳ3 ShutͲIn ShutͲIn Ͳ 1Ͳ4 30#Linear DFIT 15.0 1,680 1,462 35 35 1.00 30.00 2.00 2.00 0.15 1Ͳ5 ShutͲIn ShutͲIn Ͳ 1Ͳ6 30#Linear StepRateTest 15.0 8,400 3,784 90 90 1.00 30.00 2.00 2.00 0.15 1Ͳ7 30#HyborGͲi EstablishStableFluid20.0 8,400 5,900 140 140 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 1Ͳ8 30#HyborGͲi Pad 37.0 20,210 20,192 481 481 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 1Ͳ9 30#HyborGͲi ConditioningPad 100M 0.25 37.0 16,000 15,625 372 376 4,000 3,624 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 1Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 12,000 12,052 287 300 12,000 12,559 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 1Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 16,000 16,002 381 414 32,000 31,193 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 1Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 16,000 16,324 389 430 48,000 38,746 1.00 0.25 1.00 0.22 30.00 2.00 2.00 0.15 1Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 10,000 9,975 238 279 40,000 39,141 1.00 0.25 1.00 0.22 30.00 2.00 2.00 0.15 1Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 8,000 7,983 190 229 36,000 36,465 1.00 0.25 1.00 0.22 30.00 2.00 3.00 0.15 1Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 6,400 8,879 211 252 32,000 38,204 1.00 0.25 1.00 0.22 30.00 2.00 3.00 0.15 1Ͳ16 30#HyborGͲiSpacerandDartDrop 37.0 1,596 1,588 38 38 1.00 0.25 1.00 0.22 30.00 2.00 3.00 0.15 2Ͳ1 30#HyborGͲi MinifracͲTreatment 37.0 18,105 18,226 434 434 1.00 0.25 1.00 0.22 30.00 2.00 3.00 0.15 2Ͳ2 30#Linear MinifracͲFlush37.0 14,164 14,178 338 338 1.00 30.00 2.00 3.00 0.15 2Ͳ3 ShutͲIn ShutͲIn Ͳ 2Ͳ4 30#HyborGͲi EstablishStableFluid15.0 8,400 6,100 145 145 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ5 30#HyborGͲi Pad 37.0 9,575 9,575 228 228 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ6 30#HyborGͲi ConditioningPad 100M 0.25 37.0 16,000 16,569 395 398 4,000 2,773 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,600 2,597 62 64 2,600 2,444 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 3,270 3,242 77 84 6,540 6,629 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 5,230 5,199 124 140 15,690 15,488 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 6,340 6,294 150 177 25,360 25,140 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 6,530 6,519 155 186 29,385 29,279 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 7,080 7,061 168 205 35,400 34,275 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 2Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 7,190 7,180 171 211 39,545 37,285 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 2Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 7,580 9,742 232 284 45,480 49,407 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 2Ͳ15 30#HyborGͲiSpacerandDartDrop 37.0 1,596 2,017 48 48 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 3Ͳ1 30#HyborGͲi Pad 37.0 7,810 7,896 188 188 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37.0 16,000 16,161 385 388 4,000 2,816 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,931 46 48 2,000 1,571 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,482 59 64 5,000 4,841 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,996 95 108 12,000 11,745 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,858 116 136 19,400 18,811 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,984 119 142 22,500 21,699 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,402 129 156 27,050 26,114 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,487 131 162 30,250 29,230 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 3Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,829 139 175 34,800 34,387 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 3Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,024 96 124 26,000 26,414 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 3Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 5,419 129 159 21,000 28,126 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 3Ͳ13 30#Linear Flush 37.0 13,874 13,875 330 330 1.00 30.00 2.00 3.00 0.15 3Ͳ14 FreezeProtect FreezeProtect 10.0 1,500 1,500 36 36 3Ͳ15 ShutͲIn ShutͲIn Ͳ 50Ͳ103Ͳ20889 909746254 LiquidAdditives DryAdditives Interval 1Moraine@ 20989.08 - 20993.42 ft 138.5 °FInterval 2Moraine@ 20561.76 - 20566.1 ft 138.5 °FInterval 3Moraine@ 20108.31 - 20112.65 ft 138.6 °FConocoPhillipsͲ3TͲ608 ActualDesign 4 CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDE BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6PropCum. Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) lb 50Ͳ103Ͳ20889 909746254 LiquidAdditives DryAdditives 4Ͳ1 ShutͲIn ShutͲIn Ͳ 4Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 1,302 31 31 4Ͳ3 ShutͲIn ShutͲIn Ͳ 4Ͳ4 30#Linear SpacerandDartDrop 15.0 1,260 1,825 43 43 1.00 30.00 2.00 2.00 0.15 4Ͳ5 30#HyborGͲi EstablishStableFluid15.0 8,400 7,807 186 186 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ6 30#HyborGͲi Pad 37.0 7,810 7,808 186 186 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ7 30#HyborGͲi ConditioningPad 100M 0.25 37.0 16,000 16,280 388 392 4,000 4,466 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,021 48 50 2,000 1,572 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,481 59 64 5,000 4,997 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,999 95 108 12,000 11,879 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 5,855 139 164 19,400 23,031 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,841 115 138 22,500 21,075 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,287 126 152 27,050 24,794 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,435 129 159 30,250 27,957 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 4Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,768 137 172 34,800 33,010 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 4Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,932 94 120 26,000 24,937 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 4Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 5,120 122 150 21,000 26,564 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 4Ͳ18 30#Linear Flush 37.0 13,596 13,604 324 324 1.00 30.00 2.00 3.00 0.15 4Ͳ19 FreezeProtect FreezeProtect 5.0 1,500 1,680 40 40 4Ͳ20 ShutͲIn ShutͲIn ͲInterval 4Moraine@ 19654.3 - 19658.64 ft 138.6 °FConocoPhillipsͲ3TͲ608 ActualDesign 5 CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDE BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6PropCum. Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) lb 50Ͳ103Ͳ20889 909746254 LiquidAdditives DryAdditives 5Ͳ1 ShutͲIn ShutͲIn Ͳ 5Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 1,218 29 29 5Ͳ3 ShutͲIn ShutͲIn Ͳ 5Ͳ4 30#Linear SpacerandDartDrop 15.0 1,260 1,292 31 31 1.00 30.00 2.00 2.00 0.15 5Ͳ5 30#Linear DisplaceDarttoSeat 15.0 13,431 12,169 290 290 1.00 30.00 2.00 2.00 0.15 5Ͳ6 30#Linear DFIT 10.0 1,680 1,634 39 39 1.00 30.00 2.00 2.00 0.15 5Ͳ7 ShutͲIn ShutͲIn Ͳ 5Ͳ8 30#HyborGͲi EstablishStableFluid20.0 8,400 7,306 174 174 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ9 30#HyborGͲi Pad 37.0 7,810 7,856 187 187 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ10 30#HyborGͲi ConditioningPad 100M 0.25 37.0 16,000 16,876 402 406 4,000 3,702 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,041 49 51 2,000 2,119 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,502 60 65 5,000 4,778 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,992 95 107 12,000 11,653 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,848 115 136 19,400 18,945 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 5,006 119 143 22,500 22,100 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,388 128 156 27,050 26,056 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 5Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,440 130 158 30,250 26,663 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 5Ͳ18 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,795 138 174 34,800 33,672 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 5Ͳ19 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,146 99 128 26,000 27,292 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 5Ͳ20 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,968 118 147 21,000 27,288 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 5Ͳ21 30#HyborGͲiSpacerandDartDrop 37.0 1,596 1,957 47 47 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ1 30#HyborGͲi Pad 37.0 7,810 7,875 188 188 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37.0 16,000 18,589 443 446 4,000 3,436 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,008 48 50 2,000 1,611 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,527 60 65 5,000 4,950 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,035 96 109 12,000 12,144 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,905 117 137 19,400 19,018 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,995 119 142 22,500 21,939 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,428 129 157 27,050 26,458 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,525 132 162 30,250 29,078 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 7Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,834 139 176 34,800 34,729 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 7Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,025 96 124 26,000 26,255 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 7Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,504 107 132 21,000 23,476 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 7Ͳ13 30#HyborGͲiSpacerandDartDrop 37.0 1,596 1,786 43 43 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 8Ͳ1 30#HyborGͲi Pad 37.0 7,810 7,848 187 187 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37.0 16,000 16,216 386 390 4,000 3,866 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,982 47 49 2,000 1,667 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,497 59 65 5,000 5,043 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,965 94 107 12,000 11,841 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,755 113 133 19,400 18,680 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,963 118 141 22,500 21,273 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,404 129 156 27,050 25,705 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,488 131 161 30,250 28,795 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 8Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,833 139 176 34,800 34,593 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 8Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,953 94 122 26,000 25,803 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 8Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,967 118 146 21,000 26,335 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 8Ͳ13 30#HyborGͲiSpacerandDartDrop 37.0 1,596 1,638 39 39 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 9Ͳ1 30#HyborGͲi Pad 37.0 7,810 7,827 186 186 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37.0 16,000 17,054 406 410 4,000 3,462 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,916 46 47 2,000 1,372 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,469 59 64 5,000 4,539 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,007 95 108 12,000 11,577 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,838 115 136 19,400 19,151 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 5,006 119 143 22,500 22,539 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,436 129 157 27,050 26,371 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,484 131 162 30,250 29,241 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 9Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,800 138 174 34,800 33,893 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 9Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,028 96 123 26,000 25,885 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 9Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,840 115 142 21,000 24,936 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 9Ͳ13 30#HyborGͲiSpacerandDartDrop 37.0 1,596 1,710 41 41 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 10Ͳ1 30#HyborGͲi Pad 37.0 7,810 7,969 190 190 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37.0 16,000 16,027 382 386 4,000 3,918 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,994 47 49 2,000 1,500 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,481 59 64 5,000 4,470 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,002 95 107 12,000 11,440 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,851 116 136 19,400 19,198 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,999 119 142 22,500 22,038 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,385 128 156 27,050 25,960 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,502 131 162 30,250 29,361 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 10Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,798 138 174 34,800 34,106 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 10Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,026 96 123 26,000 25,936 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 10Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 5,268 125 153 21,000 25,846 1.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 10Ͳ13 30#Linear Flush 37.0 11,821 11,839 282 282 1.00 30.00 2.00 3.00 0.15 10Ͳ14 FreezeProtect FreezeProtect 10.0 1,470 1,302 31 31 10Ͳ15 ShutͲIn ShutͲIn ͲInterval 7Moraine@ 18125.66 - 18130 ft 138.8 °FInterval 8Moraine@ 17671.64 - 17675.98 ft 138.7 °FInterval 9Moraine@ 17174.33 - 17178.67 ft 138.6 °FInterval 10Moraine@ 16680.58 - 16684.92 ft 138.6 °FInterval 5Moraine@ 19199.27 - 19203.61 ft 138.7 °FConocoPhillipsͲ3TͲ608 ActualDesign 6 CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDE BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6PropCum. Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) lb 50Ͳ103Ͳ20889 909746254 LiquidAdditives DryAdditives 11Ͳ1 ShutͲIn ShutͲIn Ͳ 11Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,000 1,260 30 30 11Ͳ3 ShutͲIn ShutͲIn Ͳ 11Ͳ4 30#Linear SpacerandDartDrop 15.0 1,260 1,244 30 30 1.00 30.00 2.00 2.00 0.15 11Ͳ5 30#Linear DisplaceDarttoSeat 15.0 10,346 10,908 260 260 1.00 30.00 2.00 2.00 0.15 11Ͳ6 30#Linear DFIT 20.0 1,680 1,670 40 40 1.00 30.00 2.00 2.00 0.15 11Ͳ7 ShutͲIn ShutͲIn Ͳ 11Ͳ8 30#HyborGͲi EstablishStableFluid20.0 8,400 9,034 215 215 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 11Ͳ9 30#HyborGͲi Pad 37.0 7,810 7,786 185 185 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 11Ͳ10 30#HyborGͲi ConditioningPad 100M 0.25 37.0 16,000 18,138 432 436 4,000 3,555 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 11Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,977 47 48 2,000 825 1.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 11Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,395 57 61 5,000 3,737 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 11Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,969 95 105 12,000 9,906 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 11Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,852 116 134 19,400 17,119 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 11Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,964 118 140 22,500 20,188 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 11Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,394 128 155 27,050 24,816 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 11Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,459 130 159 30,250 27,722 1.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 11Ͳ18 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,816 138 174 34,800 33,367 1.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 11Ͳ19 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,994 95 122 26,000 24,943 1.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 11Ͳ20 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 6,866 163 204 21,000 38,489 1.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 11Ͳ21 30#HyborGͲiSpacerandDartDrop 37.0 1,596 1,700 40 40 1.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 12Ͳ1 30#HyborGͲi Pad 37.0 7,810 7,828 186 186 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37.0 16,000 16,576 395 399 4,000 4,336 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,964 47 48 2,000 1,411 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,310 55 59 5,000 4,143 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,987 95 107 12,000 10,899 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,803 114 133 19,400 17,931 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 5,018 119 142 22,500 20,957 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,403 129 156 27,050 25,499 1.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,483 131 159 30,250 26,895 1.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 12Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,779 138 172 34,800 32,291 1.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 12Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,014 96 122 26,000 24,440 1.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 12Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 7,478 178 214 21,000 33,927 1.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 12Ͳ13 30#Linear Flush 37.0 11,188 11,208 267 267 1.00 30.00 2.00 3.00 0.15 12Ͳ14 FreezeProtect FreezeProtect 10.0 1,470 1,260 30 30 12Ͳ15 ShutͲIn ShutͲIn Ͳ 956,192 983,028 23,405 25,783 2,244,000 2,237,786 DesignTotal(gal)ActualTotal(gal)DesignTotal(lbs)CalculatedTotal(lbs)TicketTotal(lbs)CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6PropCum. 2,200,000 2,197,832 2,271,907 (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs) (lbs) 104,899 100,692 44,000 39,954 48,000 InitialDesignMaterialVolume 840.1 210.0 945.0 210.4 28,350.3 1,890.0 2,188.0 141.8 Ͳ ͲͲ Ͳ ActualDesignMaterialVolume 871.3 217.8 972.0 218.3 29,160.2 1,944.0 2,270.7 145.8 Ͳ 10,440 11,022 Ͳ5742 ͲͲ Ͳ PhysicalMaterialVolumePumped 910 210 947 230 28951 1,950 2,250 186 Ͳ 840,112 871,314 ͲͲ Ͳ PhysicalMaterialVolumeDeviance 4%Ͳ4%Ͳ3% 5%Ͳ1% 0%Ͳ1% 28%Ͳ ͲͲ **IFSnumbersforproppantaretakenfromsoftwarecalculationsbasedonmultiplevariables MicroMotionVolumePumped 862 216 967 215 32,647 1,931 2,269 ͲͲ ͲͲ **ProppantisbilledfromWeightTicketvolumes MicroMotionVolumeDeviance Ͳ1%Ͳ1%Ͳ1%Ͳ1% 12%Ͳ1% 0%ͲͲ ͲͲ Ͳ FluidType 30#HyborG 30#Linear Seawater FreezeProtect 30#HyborGͲi ProppantType Wanli16/20Ceramic 100M Ͳ Ͳ Ͳ Ͳ ͲInterval 11Moraine@ 16185.51 - 16189.85 ft 138.7 °FInterval 12Moraine@ 15690.17 - 15694.51 ft 138.8 °FConocoPhillipsͲ3TͲ608 ActualDesign 7 ConocoPhillips Moraine 3TͲ608 50Ͳ103Ͳ20889 *Exceeds80%ofburstpressure* Description OD(in) ID(in) Wt(#) Grade FUF (gal/ft) MDTop (ft)MDBtm(ft) Volume(gal)TubularBurst Pressure(psi) Tubing 4.5 3.958 12.6 LͲ80 0.6392 0 8,148 5,208 8,430 Tubing 4.5 3.958 12.6 LͲ80 0.6392 8,148 22,000 8,854 8,430 Total 22,000 14,062 ft 1.55 ft 139.9 ft ft 1.55 ft 139.9 ft TopMD (ft)BtmMD(ft)Average TVD(ft)Interval# FormationDescriptor AverageInterval Temperature(F) BallDropTime (HH:MM) BallHitTime (HH:MM) JSVDrop (bbl) JSVSlow Down(bbl)JSVHit(bbl)Early(bbl)SurfaceSeat Pressure(psi) SurfacePeak Pressure(psi)SurfaceDifferential(psi)BHSeat Pressure(psi) BHPeak Pressure(psi) BH Differential (psi) RateatShift (bpm) Toe 20,989 20,993 5,063 1 Moraine 138.5 Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ ͲͲ Ͳ ͲͲͲͲ 20,562 20,566 5,067 2 Moraine 138.5 12:53:00PM 1:02:00PM 3,057 3,330 3,349 20.9 2,7336,3483,6154,1797,7053,52611.4 20,108 20,113 5,070 3 Moraine 138.6 3:17:00PM 3:27:00PM 5,997 6,263 6,297 6.0 3,0496,5063,4574,4017,6263,22512.5 19,654 19,659 5,074 4 Moraine 138.6 12:51:00PM 1:11:00PM 32 291 321 9.9 2,7576,2623,5053,9727,4463,47411.6 19,199 19,204 5,077 5 Moraine 138.7 10:26:00AM 10:45:00AM 41 293 320 13.2 2,3405,7373,3974,2647,4953,23112.2 18,661 18,665 5,084 6 Moraine 138.8 ͲͲͲͲͲͲ ͲͲ Ͳ ͲͲͲͲ 18,126 18,130 5,087 7 Moraine 138.8 12:14:00PM 12:23:00PM 2,445 2,681 2,713 7.9 2,9036,3213,4184,4157,8433,42811.9 17,672 17,676 5,079 8 Moraine 138.7 1:10:00PM 1:19:00PM 4,379 4,608 4,634 13.9 2,5356,1303,5953,9937,5723,57912.0 17,174 17,179 5,072 9 Moraine 138.6 2:05:00PM 2:13:00PM 6,248 6,469 6,496 13.4 2,5165,9593,4433,9517,1053,15411.9 16,681 16,685 5,070 10 Moraine 138.6 2:59:00PM 3:07:00PM 8,141 8,355 8,379 15.9 2,4295,9133,4843,8587,1493,29112.1 16,186 16,190 5,075 11 Moraine 138.7 11:56:00AM 12:13:PM 28 234 262 12.1 1,8325,4533,6213,7267,2613,53511.9 15,690 15,695 5,084 12 Moraine 138.8 1:58:00PM 2:05:00PM 2,507 2,706 2,728 17.8 2,3766,1373,7613,7847,4633,67912.3 275.9 268.9 261.4 253.9 246.3 238.810,029 11,586 11,296 10,978 10,662 10,346 12,853 306.0 12,563 12,272 11,928 DisplacementtoTop Sleeve/Perf(gal)(BBLS) 13,416 319.4 13,143 312.9 299.1 292.2 284.0 Interval# 1 MaxPressure(psi) 8,500 IsolationType CementedLiner TreatmentTubulars Customer Formation Lease API Date TemperatureData Temp.Gradient(°F/100ft) BHST(°F) DirectionalData 5,098 2,237 22,000 DirectionalData 2,237 12/9/2024 KOP TemperatureData Sleeve/PerfDepth Sleeves 7 8 9 10 11 2 3 4 5 6 12 Temp.Gradient(°F/100ft) BHST(°F)TVDatBottomPerf MDatBottomPerf 5,157 20,993 KOP Avg.TVD TotalMD ConocoPhillipsͲ3TͲ608 WellboreInformation 8 12/9/24 10:23 12/9/24 13:02 159 min -bpm -psi -psi -bbl 37.3 bpm 4,184 psi 5,341 psi 33.7 bpm 3,631 psi 3,468 psi 4,630 psi 2,997 hhp 393 psi 386 psi 664 psi 5.19 ppg 6 6 32 % 31 % 23 cP 91 F 9.0 DFIT 7.643 bpm 1827 psi 3740 psi 10.35 bpm 1855 psi 3772 psi 3145 psi 0.621 psi/ft 196,308 lbs 3,624 lbs 199,932 lbs 199,932 lbs 5,246 gal 125 bbls 1,500 gal 36 bbls 114,520 gal 2,727 bbls 20,192 gal 481 bbls 15,625 gal 372 bbls 71,215 gal 1,696 bbls 1,588 gal 38 bbls 3,784 gal 90 bbls 5,900 gal 140 bbls 1,462 gal 35 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep:Dan Faur William Martin Total Proppant Pumped* : Fluid Summary (by fluid description) Fluid Summary (by stage description) 30# Hybor G-i Volume: Establish Stable Fluid Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Step Rate Test Volume: Spacer and Dart Drop Volume: Interval Status: Creighton Moore Greg Koester A DFIT and Step Rate Test were pumped at the beginning of this interval. During 3 ppg, sand was cut due to losing prime on the blender from a tank that ran dry. Proppant was resumed and the stage was pumped to completion. Early in the 1 ppg sand stage, the BH Gauge data froze and could not be fixed until after the stage. All sand was pumped. DFIT Volume: Proppant Summary Minifrac Average Pressure: Minifrac Average DH Pressure: Freeze Protect Volume: Average Visc: Average Temp: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Max Rate: Max Surface Pressure: Max BH Pressure: Interval Summary 3T-608 - Moraine - Interval 1 Interval Summary Start Date/Time: End Date/Time: Average Surface Pressure: Average Rate: Max OA Pressure: Pumps Starting Stage: Pad Percentage Design Average Missile HHP: Initial BH Pressure (Breakdown): Average BH Pressure: Pumps Ending Stage: Max Proppant Concentration: Pump Time: Conditioning Pad Volume: Proppant Laden Fluid Volume: ISDP: Final Fracture Gradient: Pad Volume: Minifrac Max Surface Pressure: 100M Pumped: Proppant in Formation: 30# Linear Volume: Minifrac Max DH Pressure: Dart/Ball Early : Average pH: Minifrac Average Rate: Pad Percentage Actual Wanli 16/20 Ceramic Pumped: Diagnostic method Average Missile Pressure: Minifrac Max Rate: Open Well Pressure: Initial OA Pressure: ConocoPhillipsͲ3TͲ608 IntervalSummary 9 12/9/24 13:02 12/9/24 15:27 145 min 11.4 bpm 6,348 psi 7,705 psi 21 bbl 37.3 bpm 4,590 psi 5,564 psi 33.6 bpm 3,926 psi 3,746 psi 4,995 psi 3,235 hhp 867 psi 625 psi 635 psi 6.17 ppg 6 5 32 % 32 % 28 cP 74.5 F 8.7 MiniFrac 29.420 bpm 3667 psi 4954 psi 37.31 bpm 6348 psi 7705 psi 3307 psi 0.653 psi/ft 3260 psi 3237 psi 3226 psi Minifrac Average Pressure: Minifrac Average DH Pressure: Final 15 min: Interval Summary Start Date/Time: End Date/Time: Pump Time: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Dart/Ball Early : Max Rate: Max Surface Pressure: Max BH Pressure: Average Rate: Average Missile Pressure: Average Surface Pressure: Minifrac Average Rate: 3T-608 - Moraine - Interval 2 Average BH Pressure: Average Missile HHP: Open Well Pressure: Initial OA Pressure: Max OA Pressure: Max Proppant Concentration: Pumps Starting Stage: Pumps Ending Stage: Average Visc: Average Temp: Average pH: Diagnostic method Pad Percentage Design Pad Percentage Actual ISDP: Final Fracture Gradient: Final 5 min: Minifrac Max DH Pressure: Final 10 min: Minifrac Max Rate: Minifrac Max Surface Pressure: ConocoPhillipsͲ3TͲ608 IntervalSummary 10 199,947 lbs 2,773 lbs 202,720 lbs 202,720 lbs 14,178 gal 338 bbls 100,321 gal 2,389 bbls 9,575 gal 228 bbls 16,569 gal 395 bbls 47,834 gal 1,139 bbls 2,017 gal 48 bbls 6,100 gal 145 bbls 18,226 gal 434 bbls 14,178 gal 338 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Interval Status: A MiniFrac was pumped at the beginning of Interval 2 and decline was observed for 1 hour. The interval was pumped to completion. *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number.Dan Faur William Martin Creighton Moore Greg Koester Wanli 16/20 Ceramic Pumped: 100M Pumped: Total Proppant Pumped* : 30# Linear Volume: Conditioning Pad Volume: Proppant Laden Fluid Volume: Spacer and Dart Drop Volume: Establish Stable Fluid Volume: 30# Hybor G-i Volume: Proppant Summary Proppant in Formation: Fluid Summary (by fluid description) Fluid Summary (by stage description) Pad Volume: Minifrac - Treatment Volume: Minifrac - Flush Volume: ConocoPhillipsͲ3TͲ608 IntervalSummary 11 12/9/24 15:27 12/9/24 16:23 56 min 12.5 bpm 6,506 psi 7,626 psi 6 bbl 37.2 bpm 5,148 psi 6,546 psi 33.9 bpm 4,192 psi 4,004 psi 5,313 psi 3,487 hhp 594 psi 640 psi 7.38 ppg 5 4 32 % 31 % 28 cP 84.8 F 8.8 3390 psi 0.669 psi/ft 3352 psi 3295 psi 3252 psi 202,938 lbs 2,816 lbs 205,754 lbs 205,754 lbs 13,875 gal 330 bbls 1,500 gal 36 bbls 68,469 gal 1,630 bbls 7,896 gal 188 bbls 16,161 gal 385 bbls 44,412 gal 1,057 bbls 13,875 gal 330 bbls 1,500 gal 36 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: William Martin Creighton Moore Greg Koester Interval Status: During 7 ppg proppant, rate was dropped due to losing a pump due to bad valves and seats. The interval was finished at 32 bpm. The interval was pumped to completion. *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Total Proppant Pumped* : Proppant in Formation: Fluid Summary (by fluid description) Proppant Laden Fluid Volume: Flush Volume: Freeze Protect Volume: Dan Faur 3T-608 - Moraine - Interval 3 End Date/Time: Max BH Pressure: Average Rate: Initial BH Pressure (Breakdown): Dart/Ball Early : Max Rate: Max Surface Pressure: Pump Time: Initial Rate (Breakdown): Fluid Summary (by stage description) Conditioning Pad Volume: Initial Surface Pressure (Breakdown): Start Date/Time: Pad Percentage Design Pad Percentage Actual Freeze Protect Volume: Final Fracture Gradient: Average Visc: Initial OA Pressure: ISDP: Average Missile HHP: Average Temp: Average Missile Pressure: Average Surface Pressure: Average BH Pressure: Pumps Starting Stage: Pumps Ending Stage: Average pH: Final 5 min: 30# Linear Volume: 30# Hybor G-i Volume: 100M Pumped: Max OA Pressure: Max Proppant Concentration: Interval Summary Wanli 16/20 Ceramic Pumped: Pad Volume: Proppant Summary Final 10 min: Final 15 min: ConocoPhillipsͲ3TͲ608 IntervalSummary 12 12/10/24 12:49 12/10/24 14:15 86 min 11.6 bpm 6,262 psi 7,446 psi 10 bbl 37.3 bpm 5,831 psi 7,067 psi 32.5 bpm 4,308 psi 4,130 psi 5,390 psi 3,426 hhp 552 psi 0 psi 707 psi 7.11 ppg 6 4 32 % 31 % 28 cP 101.3 F 8.7 3385 psi 0.667 psi/ft 3303 psi 3261 psi 3220 psi 199,816 lbs 4,466 lbs 204,282 lbs 204,282 lbs 15,429 gal 367 bbls 2,982 gal 71 bbls 76,634 gal 1,825 bbls 7,808 gal 186 bbls 16,280 gal 388 bbls 44,739 gal 1,065 bbls 1,825 gal 43 bbls 13,604 gal 324 bbls 1,680 gal 40 bbls 7,807 gal 186 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep:Dan Faur William Martin Creighton Moore During the second half of the proppant stages, 1 pump went down for a mechanical issue, another pump went down for a pinhole leak on the suction manifold, and 2 more pumps were struggling with valve issues. Rate was limited to 32 bpm and the decision was made to flush the well and do pump maintenance. The stage was pumped to completion. Greg Koester Pad Volume: Conditioning Pad Volume: Freeze Protect Volume: Proppant Laden Fluid Volume: Fluid Summary (by stage description) Establish Stable Fluid Volume: Interval Status: Max BH Pressure: Proppant Summary Wanli 16/20 Ceramic Pumped: Total Proppant Pumped* : Pad Percentage Design Average Surface Pressure: Pumps Starting Stage: Final Fracture Gradient: Final 5 min: 100M Pumped: ISDP: Max OA Pressure: Max Proppant Concentration: Average Visc: Final 10 min: Final 15 min: Average Temp: Average pH: Initial OA Pressure: Initial Surface Pressure (Breakdown): End Date/Time: Pump Time: 3T-608 - Moraine - Interval 4 Interval Summary Start Date/Time: Initial BH Pressure (Breakdown): Open Well Pressure: Dart/Ball Early : Max Rate: Flush Volume: Average Rate: Average Missile Pressure: Average BH Pressure: Average Missile HHP: Pumps Ending Stage: Pad Percentage Actual 30# Linear Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Initial Rate (Breakdown): Proppant in Formation: Max Surface Pressure: Freeze Protect Volume: 30# Hybor G-i Volume: Fluid Summary (by fluid description) Spacer and Dart Drop Volume: ConocoPhillipsͲ3TͲ608 IntervalSummary 13 12/11/24 10:23 12/11/24 12:14 111 min 12.2 bpm 5,737 psi 7,495 psi 13 bbl 37.8 bpm 5,001 psi 5,130 psi 33.4 bpm 4,281 psi 4,132 psi 5,434 psi 3,500 hhp 638 psi 0 psi 701 psi 7.58 ppg 6 5 32 % 32 % 29 cP 93.5 F 8.8 DFIT 10.070 bpm 3517 psi 5428 psi 10.14 bpm 3825 psi 5817 psi 4265 psi 0.840 psi/ft 3360 psi 3286 psi 3237 psi 200,566 lbs 3,702 lbs 204,268 lbs 204,246 lbs 15,095 gal 359 bbls 1,218 gal 29 bbls 78,121 gal 1,860 bbls 12,169 gal 290 bbls 7,856 gal 187 bbls 16,876 gal 402 bbls 44,126 gal 1,051 bbls 3,249 gal 77 bbls 7,306 gal 174 bbls 1,634 gal 39 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: End Date/Time: Max BH Pressure: Average Surface Pressure: Interval Summary Minifrac Max Surface Pressure: Final 10 min: Final 15 min: Proppant Summary Fluid Summary (by fluid description) Fluid Summary (by stage description) Minifrac Average Rate: Minifrac Average Pressure: Minifrac Average DH Pressure: Minifrac Max Rate: Wanli 16/20 Ceramic Pumped: Conditioning Pad Volume: Freeze Protect Volume: 30# Linear Volume: 100M Pumped: Diagnostic method Displace Dart to Seat Volume: 3T-608 - Moraine - Interval 5 Average BH Pressure: Initial OA Pressure: Max Proppant Concentration: Start Date/Time: Pad Percentage Design Average Rate: Proppant in Formation: Pad Volume: 30# Hybor G-i Volume: Final 5 min: William Martin Average Missile HHP: Open Well Pressure: Average Visc: Max Surface Pressure: DFIT Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Average pH: Pad Percentage Actual Dan Faur Greg Koester Pump Time: ISDP: Creighton Moore During 5.5 ppg, sand concentration dropped due to a bin swap. In flush pump 670 shut off due to a mechanical issue but was reengaged. Pumps Starting Stage: Pumps Ending Stage: Final Fracture Gradient: Average Missile Pressure: Max OA Pressure: Initial BH Pressure (Breakdown): Dart/Ball Early : Average Temp: Initial Surface Pressure (Breakdown): Max Rate: Establish Stable Fluid Volume: Spacer and Dart Drop Volume: Total Proppant Pumped* : Initial Rate (Breakdown): Proppant Laden Fluid Volume: Minifrac Max DH Pressure: Interval Status: ConocoPhillipsͲ3TͲ608 IntervalSummary 14 Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: 3T-608 - Moraine - Interval 6 Interval Summary Sleeve intentionally not opened due to formation properties. - - - *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number.- ConocoPhillipsͲ3TͲ608 IntervalSummary 15 12/11/24 12:14 12/11/24 13:10 56 min 11.9 bpm 6,321 psi 7,843 psi 8 bbl 37.3 bpm 4,633 psi 5,838 psi 34.9 bpm 3,707 psi 3,570 psi 4,862 psi 3,173 hhp 689 psi 717 psi 7.31 ppg 5 5 32 % 34 % 28 cP 89 F 8.8 199,658 lbs 3,436 lbs 203,094 lbs 203,055 lbs 72,036 gal 1,715 bbls 7,875 gal 188 bbls 18,589 gal 443 bbls 43,786 gal 1,043 bbls 1,786 gal 43 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Interval Status: Interval pumped to completion. Fluid Summary (by fluid description) Dan Faur William Martin Greg Koester Fluid Summary (by stage description) Creighton Moore Spacer and Dart Drop Volume: Interval Summary Pump Time: Max Rate: Initial BH Pressure (Breakdown): Start Date/Time: Pumps Ending Stage: Pad Volume: 30# Hybor G-i Volume: 100M Pumped: Average pH: Max Proppant Concentration: Dart/Ball Early : Pad Percentage Actual Initial OA Pressure: Pad Percentage Design Pumps Starting Stage: Proppant Summary Proppant in Formation: Proppant Laden Fluid Volume: Average Visc: Max Surface Pressure: Max BH Pressure: Average Rate: Average Missile Pressure: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Max OA Pressure: Total Proppant Pumped* : *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Average BH Pressure: Average Surface Pressure: Wanli 16/20 Ceramic Pumped: Average Temp: Average Missile HHP: 3T-608 - Moraine - Interval 7 End Date/Time: Conditioning Pad Volume: ConocoPhillipsͲ3TͲ608 IntervalSummary 16 12/11/24 13:10 12/11/24 14:05 55 min 12.0 bpm 6,130 psi 7,572 psi 14 bbl 37.3 bpm 4,151 psi 5,143 psi 34.8 bpm 3,626 psi 3,478 psi 4,667 psi 3,095 hhp 617 psi 630 psi 7.21 ppg 5 5 32 % 31 % 30 cP 83 F 8.8 199,735 lbs 3,866 lbs 203,601 lbs 203,499 lbs 69,509 gal 1,655 bbls 7,848 gal 187 bbls 16,216 gal 386 bbls 43,807 gal 1,043 bbls 1,638 gal 39 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: William Martin Dan Faur Creighton Moore Greg Koester Interval Status: Interval pumped to completion. Proppant Laden Fluid Volume: Wanli 16/20 Ceramic Pumped: 100M Pumped: Proppant Summary 30# Hybor G-i Volume: Interval Summary 3T-608 - Moraine - Interval 8 Fluid Summary (by fluid description) Pad Volume: Average Visc: Total Proppant Pumped* : Conditioning Pad Volume: Average Missile HHP: Fluid Summary (by stage description) Pad Percentage Actual Pad Percentage Design Initial Surface Pressure (Breakdown): Start Date/Time: Initial BH Pressure (Breakdown): Average pH: Average Surface Pressure: Max Rate: Pumps Starting Stage: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Spacer and Dart Drop Volume: Proppant in Formation: Average Temp: Average Missile Pressure: Initial Rate (Breakdown): Max Surface Pressure: Pumps Ending Stage: Average Rate: Max Proppant Concentration: Average BH Pressure: Max OA Pressure: Initial OA Pressure: Max BH Pressure: Dart/Ball Early : End Date/Time: Pump Time: ConocoPhillipsͲ3TͲ608 IntervalSummary 17 12/11/24 14:05 12/11/24 14:59 54 min 11.9 bpm 5,959 psi 7,105 psi 13 bbl 37.2 bpm 4,281 psi 5,664 psi 35.3 bpm 3,469 psi 3,323 psi 4,589 psi 2,998 hhp 612 psi 646 psi 6.97 ppg 5 5 32 % 32 % 27 cP 91.3 F 8.8 199,504 lbs 3,462 lbs 202,966 lbs 202,933 lbs 70,415 gal 1,677 bbls 7,827 gal 186 bbls 17,054 gal 406 bbls 43,824 gal 1,043 bbls 1,710 gal 41 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Start Date/Time: End Date/Time: Pump Time: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. William Martin Creighton Moore Average Temp: Max Proppant Concentration: Pumps Starting Stage: Average Surface Pressure: Dan Faur Spacer and Dart Drop Volume: 3T-608 - Moraine - Interval 9 Conditioning Pad Volume: Proppant Laden Fluid Volume: Initial BH Pressure (Breakdown): Fluid Summary (by stage description) Average pH: Fluid Summary (by fluid description) Total Proppant Pumped* : Max Surface Pressure: Max BH Pressure: Initial Rate (Breakdown): Max Rate: Pumps Ending Stage: Initial Surface Pressure (Breakdown): Proppant Summary Wanli 16/20 Ceramic Pumped: Average Missile Pressure: Interval Summary Dart/Ball Early : Average Visc: Pad Percentage Design Max OA Pressure: Proppant in Formation: 30# Hybor G-i Volume: Initial OA Pressure: Average Rate: 100M Pumped: Pad Percentage Actual Interval Status: Pad Volume: Average Missile HHP: Greg Koester Average BH Pressure: Interval pumped to completion. ConocoPhillipsͲ3TͲ608 IntervalSummary 18 12/11/24 14:59 12/11/24 16:01 62 min 12.1 bpm 5,913 psi 7,149 psi 16 bbl 37.8 bpm 4,282 psi 5,637 psi 35.8 bpm 3,705 psi 3,560 psi 4,722 psi 3,247 hhp 597 psi 624 psi 7.12 ppg 5 4 32 % 31 % 27 cP 91.3 F 8.8 3238 psi 0.639 psi/ft 3153 psi 3090 psi 3043 psi 199,855 lbs 3,918 lbs 203,773 lbs 203,773 lbs 11,839 gal 282 bbls 1,302 gal 31 bbls 68,302 gal 1,626 bbls 7,969 gal 190 bbls 16,027 gal 382 bbls 44,306 gal 1,055 bbls 11,839 gal 282 bbls 1,302 gal 31 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Creighton Moore Greg Koester *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number.Dan Faur Initial BH Pressure (Breakdown): Pad Percentage Actual Pumps Starting Stage: Dart/Ball Early : Average Visc: Pad Percentage Design Max OA Pressure: Final 5 min: Final 10 min: Average pH: Average BH Pressure: ISDP: Final Fracture Gradient: Average Surface Pressure: Interval Summary Pump Time: Start Date/Time: 3T-608 - Moraine - Interval 10 End Date/Time: Interval pumped to completion. In flush pump 563 was dropped due to valves and seats. 30# Linear Volume: Average Missile HHP: Wanli 16/20 Ceramic Pumped: Freeze Protect Volume: Initial OA Pressure: Max Proppant Concentration: Flush Volume: Proppant Laden Fluid Volume: Final 15 min: 100M Pumped: Pad Volume: Conditioning Pad Volume: Average Temp: Initial Surface Pressure (Breakdown): Freeze Protect Volume: Proppant Summary Average Missile Pressure: Average Rate: Total Proppant Pumped* : Proppant in Formation: Fluid Summary (by fluid description) Max Surface Pressure: Max BH Pressure: Pumps Ending Stage: Max Rate: Initial Rate (Breakdown): Interval Status: Fluid Summary (by stage description) William Martin 30# Hybor G-i Volume: ConocoPhillipsͲ3TͲ608 IntervalSummary 19 12/15/24 11:53 12/15/24 13:58 125 min 11.9 bpm 5,453 psi 7,261 psi 12 bbl 37.5 bpm 4,046 psi 5,170 psi 36.0 bpm 3,507 psi 3,366 psi 4,513 psi 3,096 hhp 548 psi 311 psi 676 psi 7.48 ppg 6 6 32 % 32 % 28 cP 80.1 F 8.6 DFIT 19.350 bpm 2788 psi 4422 psi 20.04 bpm 3145 psi 4809 psi 3096 psi 0.610 psi/ft 3039 psi 2997 psi 2959 psi 201,112 lbs 3,555 lbs 204,667 lbs 204,543 lbs 13,822 gal 329 bbls 1,260 gal 30 bbls 82,344 gal 1,961 bbls 10,908 gal 260 bbls 7,786 gal 185 bbls 18,138 gal 432 bbls 45,686 gal 1,088 bbls 2,944 gal 70 bbls 9,034 gal 215 bbls 1,670 gal 40 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Fluid Summary (by stage description) Establish Stable Fluid Volume: Pad Volume: Spacer and Dart Drop Volume: Displace Dart to Seat Volume: A DFIT was pumped at the beginning of interval 11 and pressure was monitored for 1 hour. Closure was not observed. Interval 11 was pumped to completion. Dan Faur Creighton Moore Greg Koester *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Pad Percentage Design Average Surface Pressure: Max OA Pressure: Max BH Pressure: Average Rate: Average BH Pressure: Interval Summary Minifrac Max Rate: Minifrac Max Surface Pressure: Proppant Summary Fluid Summary (by fluid description) Total Proppant Pumped* : Proppant in Formation: Pumps Ending Stage: Pump Time: Initial BH Pressure (Breakdown): Dart/Ball Early : 3T-608 - Moraine - Interval 11 End Date/Time: Max Proppant Concentration: Average Visc: Minifrac Average DH Pressure: Average Temp: Final 5 min: Minifrac Average Rate: Final 15 min: Max Rate: Wanli 16/20 Ceramic Pumped: Minifrac Max DH Pressure: Average pH: Pad Percentage Actual Initial OA Pressure: William Martin Minifrac Average Pressure: Open Well Pressure: Pumps Starting Stage: ISDP: 100M Pumped: Conditioning Pad Volume: 30# Hybor G-i Volume: DFIT Volume: Proppant Laden Fluid Volume: Final Fracture Gradient: Freeze Protect Volume: Final 10 min: Start Date/Time: Interval Status: Average Missile HHP: 30# Linear Volume: Diagnostic method Initial Rate (Breakdown): Average Missile Pressure: Initial Surface Pressure (Breakdown): Max Surface Pressure: ConocoPhillipsͲ3TͲ608 IntervalSummary 20 12/15/24 13:58 12/15/24 15:00 62 min 12.3 bpm 6,137 psi 7,463 psi 18 bbl 37.2 bpm 4,128 psi 5,347 psi 36.2 bpm 3,604 psi 3,459 psi 4,512 psi 3,193 hhp 634 psi 656 psi 6.78 ppg 6 6 32 % 31 % 27 cP 74.8 F 8.8 3331 psi 0.655 psi/ft 3275 psi 3244 psi 3218 psi 198,393 lbs 4,336 lbs 202,729 lbs 202,707 lbs 11,208 gal 267 bbls 1,260 gal 30 bbls 70,643 gal 1,682 bbls 7,828 gal 186 bbls 16,576 gal 395 bbls 46,239 gal 1,101 bbls 11,208 gal 267 bbls 1,260 gal 30 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Pumps Starting Stage: Max Proppant Concentration: Pump Time: 3T-608 - Moraine - Interval 12 Interval Summary Initial BH Pressure (Breakdown): Average Missile HHP: Initial Surface Pressure (Breakdown): Max OA Pressure: Average pH: Max Rate: Initial OA Pressure: End Date/Time: Dart/Ball Early : Max BH Pressure: Average Visc: Creighton Moore Dan Faur Average Surface Pressure: Freeze Protect Volume: Start Date/Time: Average Rate: Average Missile Pressure: Final Fracture Gradient: Pad Percentage Actual Initial Rate (Breakdown): Average BH Pressure: Interval 12 was pumped to completion on 12/15. This was the final stage of the toe half of this well. These intervals will be flowed before coming back to complete the remainder of the well. William Martin Proppant Summary Fluid Summary (by fluid description) Fluid Summary (by stage description) 100M Pumped: 30# Linear Volume: Freeze Protect Volume: 30# Hybor G-i Volume: Max Surface Pressure: ISDP: Interval Status: Pad Volume: Flush Volume: Conditioning Pad Volume: Greg Koester *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Final 15 min: Final 5 min: Total Proppant Pumped* : Final 10 min: Wanli 16/20 Ceramic Pumped: Pumps Ending Stage: Pad Percentage Design Proppant in Formation: Proppant Laden Fluid Volume: Average Temp: ConocoPhillipsͲ3TͲ608 IntervalSummary 21 Customer Formation Lease API Date WellSummary Wanli16/20Ceramic 100M TotalProppant BHPressure Rate Visc Temp pH rfacePress Rate gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs lbs 1 4630 33.7 23 91 9.0 4184 37.3 5,2461251,50036114,5202,727121,2662,887196,3083,624199,932 2 4995 33.6 28 75 8.7 4590 37.3 14,178338100,3212,389114,4992,726199,9472,773202,720 3 5313 33.9 28 85 8.8 5148 37.2 13,8753301,5003668,4691,63083,8441,996202,9382,816205,754 4 5390 32.5 28 101 8.7 5831 37.3 15,4293672,9827176,6341,82595,0452,263199,8164,466204,282 5 5434 33.4 29 94 8.8 5001 37.8 15,0953591,2182978,1211,86094,4342,248200,5663,702204,268 6 0 0.0 0 0 0.0 0 0.0 7 4862 34.9 28 89 8.8 4633 37.3 72,0361,71572,0361,715199,6583,436203,094 8 4667 34.8 30 83 8.8 4151 37.3 69,5091,65569,5091,655199,7353,866203,601 9 4589 35.3 27 91 8.8 4281 37.2 70,4151,67770,4151,677199,5043,462202,966 10 4722 35.8 27 91 8.8 4282 37.8 11,8392821,3023168,3021,62681,4431,939199,8553,918203,773 11 4513 36.0 28 80 8.6 4046 37.5 13,8223291,2603082,3441,96197,4262,320201,1123,555204,667 12 4512 36.2 27 75 8.8 4128 37.2 11,2082671,2603070,6431,68283,1111,979198,3934,336202,729 Minimum 52461251218296830216266950916551963082773199932 Average 125873001575377921018868936621281998033632203435 Maximum 15429367298271114520272712126628872029384466205754 Wanli16/20Ceramic 100M TotalProppant Pressure Rate Visc Temp pH Pressure Rate gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs Total Planned 104,899 2,498 0 0 10,440 249 840,112 20,003 955,451 22,749 2,200,000 44,000 2,244,000 Recorded 4469 31.7 25 80 8.05 5831 37.8 100,692 2,397 0 0 11,022 262 871,314 20,746 983,028 23,405 2,197,832 39,954 2,237,786 WeightTickets 2,271,907 48,000 2,319,907 **ProppantisbilledfromWeightTicketvolumes **IFSnumbersforproppantaretakenfromsoftwarecalculationsbasedon TotalFluid Fluids Proppants Fluids Proppants 30#HyborGͲiTotalFluid FreezeProtect 30#HyborGͲi FreezeProtect Average Max Seawater30#Linear 30#LinearIntervalAverage Max Seawater December09,2024 50Ͳ103Ͳ20889 3TͲ608 Moraine ConocoPhillips ConocoPhillipsͲ3TͲ608 FluidSystemͲProppantSummary 22 <-Paste Interval 1 Plots HereTreatment Plot - Arsenal Burst Disk 12/4/2024 10:12 10:14 10:16 10:18 12/4/2024 10:20 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 A 0 10 20 30 40 50 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 109 Global Event Log 9 10 Intersection Intersection Open Well Other- Arsenal Disk10:11:55 10:18:38 TP TP 208.1 4789 GBP GBP 2224 6915 ConocoPhillipsͲ3TͲ608 Interval1Plots 23 <-Paste Interval 1 Plots HereTreatment Plot - Alpha Sleeve Shift 12/4/2024 10:20 10:25 10:30 10:35 12/4/2024 10:40 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 A 0 10 20 30 40 50 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 1211 Global Event Log 11 12 Intersection Intersection Other - Alpha Shift Shut In Well10:32:36 10:40:39 TP TP 6322 810.6 GBP GBP 8397 2785 ConocoPhillipsͲ3TͲ608 Interval1Plots 24 <-Paste Interval 1 Plots Here ePRV Test - 12.9 12/9/2024 08:57 08:58 08:59 09:00 09:01 09:02 09:03 12/9/2024 09:04 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 13121110 Global Event Log 10 11 12 13 Intersection Intersection ePRV - Primary Tubing ePRV - Primary IA ePRV - Secondary Tubing ePRV - Secondary IA 08:57:12 08:59:26 09:02:03 09:03:33 TP TP 224.8 603.9 564.4 735.4 TPP TPP 237.2 631.9 475.5 807.5 IGKP IGKP 500.0 500.0 500.0 500.0 ConocoPhillipsͲ3TͲ608 Interval1Plots 25 <-Paste Interval 1 Plots HerePressure Test - 12.9 12/9/2024 09:48 09:50 09:52 09:54 09:56 09:58 10:00 12/9/2024 10:02 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 1918 Global Event Log 18 19 Intersection Intersection Pressure Test - Max Pressure Test - Pass09:55:51 10:00:51 TP TP 9493 9343 TPP TPP 9591 9432 IGKP IGKP 9600 9600 PKP PKP 9500 9500 Customer: Conoco Phillips - Alaska Job Date: 09-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval1Plots 26 Blender Chemical Plot - Bucket Test 12.9 12/9/2024 08:10 08:20 08:30 08:40 12/9/2024 08:50 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A ConocoPhillipsͲ3TͲ608 Interval1Plots 27 ADP Chemical Plots - Bucket Test 12.9 12/9/2024 07:50 07:51 07:52 07:53 07:54 07:55 07:56 12/9/2024 07:57 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B ConocoPhillipsͲ3TͲ608 Interval1Plots 28 Treatment Plot - Interval 01 DFIT 12/9/2024 10:25 10:30 10:35 10:40 10:45 12/9/2024 10:50 Time 0 1000 2000 3000 4000 5000 A 0 10 20 30 40 50 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 54 ConocoPhillipsͲ3TͲ608 Interval1Plots 29 Treatment Plot - Interval 01 Step Rate Test 12/9/2024 11:12 11:14 11:16 11:18 11:20 11:22 12/9/2024 11:24 Time 0 1000 2000 3000 4000 5000 A 0 10 20 30 40 50 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 6 3635343332313029282726 Global Event Log 26 27 28 29 30 31 32 33 34 35 36 Intersection Intersection Open Well Step 1 Step 2 Step 3 Step 4 Step 5 Step 6 Step 7 Step 8 Step 9 Step 10 11:12:24 11:13:58 11:15:02 11:16:17 11:17:34 11:18:52 11:19:53 11:21:06 11:22:21 11:23:32 11:24:41 TP TP 379.7 874.0 1040 1096 1163 1238 1306 1409 1549 1685 1824 SR SR 0.000 1.200 1.941 2.985 4.018 5.228 6.074 7.044 8.046 9.017 10.02 GBP GBP 2651 3289 3362 3417 3468 3505 3538 3585 3658 3726 3804 ConocoPhillipsͲ3TͲ608 Interval1Plots 30 Treatment Plot - Interval 01 12/9/2024 11:20 11:40 12:00 12:20 12:40 12/9/2024 13:00 Time 0 1000 2000 3000 4000 5000 6000 A 0 10 20 30 40 50 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 1 1615141312111098762 ConocoPhillipsͲ3TͲ608 Interval1Plots 31 Blender Chemical Plot - Interval 01 12/9/2024 11:20 11:40 12:00 12:20 12:40 12/9/2024 13:00 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 1 1615141312111098762 ConocoPhillipsͲ3TͲ608 Interval1Plots 32 ADP Chemical Plots - Interval 01 12/9/2024 11:20 11:40 12:00 12:20 12:40 12/9/2024 13:00 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 1 161514131211109872 ConocoPhillipsͲ3TͲ608 Interval1Plots 33 Net Pressure Plot - Interval 01 3 4 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3080 psi 0 Time = 12/09/24 07:14:40 1 Time 50.95 NetPr 0.000 Slope 0.000 DH Gauge Malfunction Customer: Conoco Phillips - Alaska Job Date: 09-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval1Plots 34 <-Paste Interval 2 Plots HereTreatment Plot - Interval 02 MiniFrac 12/9/2024 13:00 13:10 13:20 12/9/2024 13:30 Time 0 1000 2000 3000 4000 5000 6000 A 0 10 20 30 40 50 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 32 1 16 2 ConocoPhillipsͲ3TͲ608 Interval2Plots 35 <-Paste Interval 2 Plots HereBlender Chemical Plot - Interval 02 MiniFrac 12/9/2024 12:55 13:00 13:05 13:10 13:15 12/9/2024 13:20 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 321162 ConocoPhillipsͲ3TͲ608 Interval2Plots 36 <-Paste Interval 2 Plots HereADP Chemical Plots - Interval 02 MiniFrac 12/9/2024 12:55 13:00 13:05 13:10 13:15 12/9/2024 13:20 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 321162 ConocoPhillipsͲ3TͲ608 Interval2Plots 37 <-Paste Interval 2 Plots HereTreatment Plot - Interval 02 12/9/2024 14:20 14:40 15:00 12/9/2024 15:20 Time 0 1000 2000 3000 4000 5000 6000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 2 1 1514131211109 8 7654 3 ConocoPhillipsͲ3TͲ608 Interval2Plots 38 Blender Chemical Plot - Interval 02 12/9/2024 14:10 14:20 14:30 14:40 14:50 15:00 15:10 12/9/2024 15:20 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 1 1514131211109 8 7654 3 ConocoPhillipsͲ3TͲ608 Interval2Plots 39 ADP Chemical Plots - Interval 02 12/9/2024 14:10 14:20 14:30 14:40 14:50 15:00 12/9/2024 15:10 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 1 151413121110987654 3 ConocoPhillipsͲ3TͲ608 Interval2Plots 40 Net Pressure Plot - Interval 02 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3080 psi 0 Time = 12/09/24 07:14:40 1 Time 50.95 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 09-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval2Plots 41 <-Paste Interval 3 Plots HereTreatment Plot - Interval 03 12/9/2024 15:20 15:30 15:40 15:50 16:00 16:10 12/9/2024 16:20 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 141312111098765 4 32 1 153 ConocoPhillipsͲ3TͲ608 Interval3Plots 42 <-Paste Interval 3 Plots HereBlender Chemical Plot - Interval 03 12/9/2024 15:20 15:30 15:40 15:50 16:00 16:10 12/9/2024 16:20 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 141312111098765 4 32 1 15 3 ConocoPhillipsͲ3TͲ608 Interval3Plots 43 <-Paste Interval 3 Plots HereADP Chemical Plots - Interval 03 12/9/2024 15:20 15:30 15:40 15:50 16:00 16:10 12/9/2024 16:20 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 141312111098765 4 32 1 15 3 ConocoPhillipsͲ3TͲ608 Interval3Plots 44 <-Paste Interval 3 Plots HereNet Pressure Plot - Interval 03 5 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3080 psi 0 Time = 12/09/24 07:14:40 1 Time 50.95 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 09-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval3Plots 45 <-Paste Interval 4 Plots Here ePRV Test - 12.10 12/10/2024 10:06 10:08 10:10 10:12 12/10/2024 10:14 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 111098 Global Event Log 8 9 10 11 Intersection Intersection ePRV - Primary Tubing ePRV - Primary IA ePRV - Secondary Tubing ePRV - Secondary IA 10:05:54 10:08:43 10:11:38 10:13:36 TP TP 448.9 490.4 452.8 325.3 TPP TPP 503.8 493.0 499.2 383.4 IGKP IGKP 500.0 500.0 500.0 500.0 ConocoPhillipsͲ3TͲ608 Interval4Plots 46 <-Paste Interval 4 Plots HerePressure Test - 12.10 12/10/2024 10:16 10:18 10:20 10:22 10:24 10:26 10:28 12/10/2024 10:30 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 17161514 Global Event Log 14 15 16 17 Intersection Intersection Pressure Test - Global Pressure Test - Locals Pressure Test - Max Pressure Test - Pass 10:15:23 10:16:03 10:21:49 10:26:50 TP TP 284.2 459.0 9528 9399 TPP TPP 288.5 508.8 9595 9452 IGKP IGKP 300.0 5000 500.0 500.0 PKP PKP 800.0 500.4 9600 9600 Customer: Conoco Phillips - Alaska Job Date: 10-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval4Plots 47 <-Paste Interval 4 Plots HereBlender Chemical Plot - Bucket Test 12.10 12/10/2024 07:20 07:25 07:30 12/10/2024 07:35 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A ConocoPhillipsͲ3TͲ608 Interval4Plots 48 <-Paste Interval 4 Plots HereADP Chemical Plots - Bucket Test 12.10 12/10/2024 09:26 09:28 09:30 09:32 12/10/2024 09:34 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B ConocoPhillipsͲ3TͲ608 Interval4Plots 49 Treatment Plot - Interval 04 12/10/2024 12:40 13:00 13:20 13:40 14:00 12/10/2024 14:20 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 1817161514131211 10 9 8765 4 3 ConocoPhillipsͲ3TͲ608 Interval4Plots 50 Blender Chemical Plot - Interval 04 12/10/2024 13:00 13:20 13:40 12/10/2024 14:00 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 181716151413121110 9 8765 ConocoPhillipsͲ3TͲ608 Interval4Plots 51 ADP Chemical Plots - Interval 04 12/10/2024 13:00 13:20 13:40 12/10/2024 14:00 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 181716151413121110 9 8765 ConocoPhillipsͲ3TͲ608 Interval4Plots 52 Net Pressure Plot - Interval 04 4 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3080 psi 0 Time = 12/10/24 06:56:56 1 Time 50.95 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 10-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval4Plots 53 <-Paste Interval 5 Plots Here ePRV Test - 12.11 12/11/2024 09:29 09:30 09:31 09:32 09:33 09:34 12/11/2024 09:35 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 1211109 Global Event Log 9 10 11 12 Intersection Intersection ePRV - Primary Tubing ePRV - Primary IA ePRV - Secondary Tubing ePRV - Secondary IA 09:29:33 09:31:18 09:33:21 09:34:54 TP TP 492.6 542.2 566.5 581.2 TPP TPP 517.8 530.2 529.7 559.1 IGKP IGKP 500.0 500.0 500.0 500.0 ConocoPhillipsͲ3TͲ608 Interval5Plots 54 <-Paste Interval 5 Plots HerePressure Test - 12.11 12/11/2024 09:36 09:38 09:40 09:42 09:44 09:46 09:48 12/11/2024 09:50 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi) I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi) 1615 14 13 Global Event Log 13 14 15 16 Intersection Intersection Pressure Test - Global Pressure Test - Locals Pressure Test Pressure Test - Pass 09:36:11 09:36:25 09:43:12 09:48:19 TP TP 578.6 578.2 9541 9372 TPP TPP 242.4 242.3 9599 9408 IGKP IGKP 250.0 250.0 9600 9600 PKP PKP 500.4 500.4 9600 9600 Customer: Conoco Phillips - Alaska Job Date: 11-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval5Plots 55 <-Paste Interval 5 Plots HereBlender Chemical Plot - Bucket Test 12.11 12/11/2024 07:00 07:02 07:04 07:06 07:08 07:10 07:12 07:14 12/11/2024 07:16 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A ConocoPhillipsͲ3TͲ608 Interval5Plots 56 <-Paste Interval 5 Plots HereADP Chemical Plots - Bucket Test 12.11 12/11/2024 06:54:30 06:55:00 06:55:30 06:56:00 06:56:30 06:57:00 06:57:30 06:58:00 12/11/2024 06:58:30 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 1 ConocoPhillipsͲ3TͲ608 Interval5Plots 57 Treatment Plot - Interval 05 DFIT 12/11/2024 10:25 10:30 10:35 10:40 10:45 10:50 12/11/2024 10:55 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 7654 ConocoPhillipsͲ3TͲ608 Interval5Plots 58 Blender Chemical Plot - Interval 05 DFIT 12/11/2024 10:25 10:30 10:35 10:40 10:45 10:50 12/11/2024 10:55 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 7654 ConocoPhillipsͲ3TͲ608 Interval5Plots 59 ADP Chemical Plots - Interval 05 DFIT 12/11/2024 10:20 10:25 10:30 10:35 10:40 10:45 12/11/2024 10:50 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 7654 ConocoPhillipsͲ3TͲ608 Interval5Plots 60 Treatment Plot - Interval 05 12/11/2024 11:20 11:40 12:00 12/11/2024 12:20 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 2 1 212019181716151413 12 111098 7 ConocoPhillipsͲ3TͲ608 Interval5Plots 61 Blender Chemical Plot - Interval 05 12/11/2024 11:10 11:20 11:30 11:40 11:50 12:00 12:10 12/11/2024 12:20 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 2 1 212019181716151413 12 111098 7 ConocoPhillipsͲ3TͲ608 Interval5Plots 62 ADP Chemical Plots - Interval 05 12/11/2024 11:10 11:20 11:30 11:40 11:50 12:00 12:10 12/11/2024 12:20 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 2 1 212019181716151413 12 111098 7 ConocoPhillipsͲ3TͲ608 Interval5Plots 63 Net Pressure Plot - Interval 05 3 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3080 psi 0 Time = 12/11/24 06:54:57 1 Time 50.95 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 11-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval5Plots 64 <-Paste Interval 7 Plots HereTreatment Plot - Interval 07 12/11/2024 12:20 12:30 12:40 12:50 13:00 13:10 12/11/2024 13:20 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 2 1 1312111098765 4 321 87 ConocoPhillipsͲ3TͲ608 Interval7Plots 65 <-Paste Interval 7 Plots HereBlender Chemical Plot - Interval 07 12/11/2024 12:20 12:30 12:40 12:50 13:00 12/11/2024 13:10 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 2 1 1312111098765 4 32 1 21 87 ConocoPhillipsͲ3TͲ608 Interval7Plots 66 <-Paste Interval 7 Plots HereADP Chemical Plots - Interval 07 12/11/2024 12:20 12:30 12:40 12:50 13:00 12/11/2024 13:10 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 2 1 1312111098765 4 32 1 21 87 ConocoPhillipsͲ3TͲ608 Interval7Plots 67 <-Paste Interval 7 Plots HereNet Pressure Plot - Interval 07 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3080 psi 0 Time = 12/11/24 06:54:57 1 Time 50.95 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 11-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval7Plots 68 <-Paste Interval 8 Plots HereTreatment Plot - Interval 08 12/11/2024 13:10 13:20 13:30 13:40 13:50 14:00 12/11/2024 14:10 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 2 1 1312111098765 4 32 1 13 98 ConocoPhillipsͲ3TͲ608 Interval8Plots 69 <-Paste Interval 8 Plots HereBlender Chemical Plot - Interval 08 12/11/2024 13:10 13:20 13:30 13:40 13:50 14:00 12/11/2024 14:10 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 2 1 1312111098765 4 32 1 13 98 ConocoPhillipsͲ3TͲ608 Interval8Plots 70 <-Paste Interval 8 Plots HereADP Chemical Plots - Interval 08 12/11/2024 13:10 13:20 13:30 13:40 13:50 14:00 12/11/2024 14:10 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 2 1 1312111098765 4 32 1 13 98 ConocoPhillipsͲ3TͲ608 Interval8Plots 71 <-Paste Interval 8 Plots HereNet Pressure Plot - Interval 08 4 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3080 psi 0 Time = 12/11/24 06:54:57 1 Time 50.95 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 11-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval8Plots 72 <-Paste Interval 9 Plots HereTreatment Plot - Interval 09 12/11/2024 14:10 14:20 14:30 14:40 14:50 12/11/2024 15:00 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 2 1 1312111098765 4 321 109 ConocoPhillipsͲ3TͲ608 Interval9Plots 73 <-Paste Interval 9 Plots HereBlender Chemical Plot - Interval 09 12/11/2024 14:10 14:20 14:30 14:40 14:50 12/11/2024 15:00 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 2 1 1312111098765 4 321 109 ConocoPhillipsͲ3TͲ608 Interval9Plots 74 <-Paste Interval 9 Plots HereADP Chemical Plots - Interval 09 12/11/2024 14:10 14:20 14:30 14:40 14:50 12/11/2024 15:00 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 2 1 1312111098765 4 32 1 13 109 ConocoPhillipsͲ3TͲ608 Interval9Plots 75 <-Paste Interval 9 Plots HereNet Pressure Plot - Interval 09 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3080 psi 0 Time = 12/11/24 06:54:57 1 Time 50.95 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 11-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval9Plots 76 <-Paste Interval 10 Plots HereTreatment Plot - Interval 10 12/11/2024 15:00 15:10 15:20 15:30 15:40 15:50 12/11/2024 16:00 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 141312111098765 4 32 1 1310 ConocoPhillipsͲ3TͲ608 Interval10Plots 77 <-Paste Interval 10 Plots HereBlender Chemical Plot - Interval 10 12/11/2024 15:00 15:10 15:20 15:30 15:40 15:50 12/11/2024 16:00 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 141312111098765 4 32110 ConocoPhillipsͲ3TͲ608 Interval10Plots 78 <-Paste Interval 10 Plots HereADP Chemical Plots - Interval 10 12/11/2024 15:00 15:10 15:20 15:30 15:40 15:50 12/11/2024 16:00 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 141312111098765 4 32 1 1310 ConocoPhillipsͲ3TͲ608 Interval10Plots 79 <-Paste Interval 10 Plots HereNet Pressure Plot - Interval 10 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3080 psi 0 Time = 12/11/24 06:54:57 1 Time 50.95 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 11-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval10Plots 80 <-Paste Interval 11 Plots HereePRV Test - 12.15 12/15/2024 08:16 08:17 08:18 08:19 08:20 08:21 12/15/2024 08:22 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 8765 Global Event Log 5 6 7 8 Intersection Intersection ePRV - Primary Tubing ePRV - Primary IA ePRV - Secondary Tubing ePRV - Secondary IA 08:16:53 08:18:14 08:19:19 08:20:56 TP TP 795.0 769.0 770.3 822.4 TPP TPP 815.1 595.3 792.9 791.7 IGKP IGKP 800.0 800.0 800.0 800.0 ConocoPhillipsͲ3TͲ608 Interval11Plots 81 <-Paste Interval 11 Plots HerePressure Test - 12.15 12/15/2024 08:40 08:42 08:44 08:46 08:48 08:50 08:52 12/15/2024 08:54 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi) I1 Global Kickout Pressure (psi)P2 Kickout Pressure (psi) 3 1211109 Global Event Log 9 10 11 12 Intersection Intersection Pressure Test - Locals Pressure Test - Global Pressure Test - Max Pressure Test - Pass 08:39:43 08:40:14 08:47:09 08:52:10 TP TP 803.1 802.4 9475 9252 TPP TPP 166.5 174.7 9508 9293 IGKP IGKP 500.0 180.0 9600 9600 PKP PKP 800.0 800.0 9600 9600 Customer: Conoco Phillips - Alaska Job Date: 15-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval11Plots 82 <-Paste Interval 11 Plots HereBlender Chemical Plot - Bucket Test 12.15 12/15/2024 07:44 07:46 07:48 07:50 07:52 07:54 12/15/2024 07:56 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A ConocoPhillipsͲ3TͲ608 Interval11Plots 83 <-Paste Interval 11 Plots HereADP Chemical Plots - Bucket Test 12.15 12/15/2024 07:38 07:40 07:42 07:44 07:46 07:48 12/15/2024 07:50 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B ConocoPhillipsͲ3TͲ608 Interval11Plots 84 Treatment Plot - Interval 11 DFIT 12/15/2024 12:14 12:16 12:18 12:20 12:22 12/15/2024 12:24 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 76 ConocoPhillipsͲ3TͲ608 Interval11Plots 85 Blender Chemical Plot - Interval 11 DFIT 12/15/2024 11:50 11:55 12:00 12:05 12:10 12/15/2024 12:15 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 7654 ConocoPhillipsͲ3TͲ608 Interval11Plots 86 ADP Chemical Plots - Interval 11 DFIT 12/15/2024 11:55 12:00 12:05 12:10 12:15 12/15/2024 12:20 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 7654 ConocoPhillipsͲ3TͲ608 Interval11Plots 87 Treatment Plot - Interval 11 12/15/2024 13:00 13:20 13:40 12/15/2024 14:00 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 2 1 212019181716151413 12 111098 12 ConocoPhillipsͲ3TͲ608 Interval11Plots 88 Blender Chemical Plot - Interval 11 12/15/2024 12:50 13:00 13:10 13:20 13:30 13:40 13:50 12/15/2024 14:00 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 2 1 212019181716151413 12 111098 12 ConocoPhillipsͲ3TͲ608 Interval11Plots 89 ADP Chemical Plots - Interval 11 12/15/2024 13:00 13:10 13:20 13:30 13:40 13:50 12/15/2024 14:00 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 2 1 212019181716151413 12 111098 12 ConocoPhillipsͲ3TͲ608 Interval11Plots 90 Net Pressure Plot - Interval 11 4 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3080 psi 0 Time = 12/15/24 06:55:17 1 Time 50.95 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 15-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval11Plots 91 <-Paste Interval 12 Plots HereTreatment Plot - Interval 12 12/15/2024 14:00 14:10 14:20 14:30 14:40 14:50 12/15/2024 15:00 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 141312111098765 4 32112 ConocoPhillipsͲ3TͲ608 Interval12Plots 92 <-Paste Interval 12 Plots HereBlender Chemical Plot - Interval 12 12/15/2024 14:00 14:10 14:20 14:30 14:40 14:50 12/15/2024 15:00 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 141312111098765 4 32 1 2112 ConocoPhillipsͲ3TͲ608 Interval12Plots 93 <-Paste Interval 12 Plots HereADP Chemical Plots - Interval 12 12/15/2024 14:00 14:10 14:20 14:30 14:40 14:50 12/15/2024 15:00 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 141312111098765 4 32 1 2112 ConocoPhillipsͲ3TͲ608 Interval12Plots 94 <-Paste Interval 12 Plots HereNet Pressure Plot - Interval 12 2 3 4 5 6 710 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3080 psi 0 Time = 12/15/24 13:55:17 1 Time -369.04 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 15-Dec-2024 Sales Order #: 0909746254 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval12Plots 95 Sales Order# Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ EventLog SieveAnalysis Fann15Minute FieldBreakTest RealͲTimeQC WellSummary Stimulation Treatment Appendix ChemicalSummary PlannedDesign WaterStraps WaterAnalysis Prepared for: Manabu Nozaki December 16, 2024 Harrison Bay County, AK 909746254 Conoco Phillips 3T-608 Intervals 1-22 Moraine Moraine Formation API: 50-103-20889 ConocoPhillipsͲ3TͲ608 Appendix 96 Interval Date Designed Proppant (lbs) Proppantin Formation (lbs) DesignedFluid (bbl) VolClean (bbl) VolSlurry (bbl) PadPercentage Design PadPercentage Actual Proppant Aggressivness (lb/bblClean) FluidSystem 1 12/9/2024 204,000199,932 3,004 2887 3,100 32.0 31.0 116 HyborͲHybrid 2 12/9/2024 204,000202,720 2,706 2726 2,942 32.0 31.6 176 HyborͲHybrid 3 12/9/2024 204,000205,754 1,934 1996 2,215 32.0 31.1 192 HyborͲHybrid 4 12/10/2024 204,000204,282 2,182 2263 2,480 32.0 31.2 188 HyborͲHybrid 5 12/11/2024 204,000204,246 2,220 2248 2,465 32.0 31.9 191 HyborͲHybrid 6 7 12/11/2024 204,000203,055 1,606 1715 1,931 32.0 33.6 192 HyborͲHybrid 8 12/11/2024 204,000203,499 1,606 1655 1,871 32.0 31.5 191 HyborͲHybrid 9 12/11/2024 204,000202,933 1,606 1677 1,892 32.0 32.2 191 HyborͲHybrid 10 12/11/2024 204,000203,773 1,885 1939 2,156 32.0 31.2 189 HyborͲHybrid 11 12/15/2024 204,000204,543 2,146 2320 2,537 32.0 32.3 185 HyborͲHybrid 12 12/15/2024 204,000202,707 1,870 1979 2,194 32.0 30.9 180 HyborͲHybrid 3TͲ608IntervalHighlights Intentionallyskippedforformationreasons ConocoPhillipsͲ3TͲ608 WellSummary 97 Customer ConocoPhillips Formation Moraine Lease 3TͲ608 API 50Ͳ103Ͳ20889 Date IntervalSummaryͲChemicals CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs) PrimeUp 00000000 1 145 40 130 55 3462 237 256 75 2 95 20 115 15 3575 227 287 0 3 55 10 67 5 2277 137 157 0 4 110 15 95 20 2884 200 250 51 5 100 20 95 20 2959 186 210 21 6 00000000 7 80 35 75 20 2079 143 172 0 8 65 15 65 15 2216 138 160 0 9 65 15 70 20 2009 140 163 0 10 50 10 70 15 2270 193 195 0 11 80 20 100 25 2934 192 215 39 12 65 10 65 20 2286 158 185 0 Total 910 210 947 230 28951 1950 2250 186 w/oPrimeUp 910 210 947 230 28951 1950 2250 186 Interval 12/9/2024 DryAdditivesLiquidAdditives ConocoPhillipsͲ3TͲ608 ChemicalSummary 98 CUSTOMER ConocoPhillipsFALSE API BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDE BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(p8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean DesignClean DesignSlurry DesignProp Stage IntervalCLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time Time Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) 1Ͳ1 ShutͲIn ShutͲIn 1:47:28 1Ͳ2 FreezeProtect PrimeUpPressureTest 5 1,500 36360:07:091:47:28 1Ͳ3 ShutͲIn ShutͲIn 1:40:20 1Ͳ4 30#Linear DFIT 15 1,680 40400:02:401:40:201.00 30.00 2.00 2.00 0.15 1Ͳ5 ShutͲIn ShutͲIn 1:37:40 1Ͳ6 30#Linear StepRateTest 15 8,400 2002000:13:201:37:401.00 30.00 2.00 2.00 0.15 1Ͳ7 30#HyborGͲi EstablishStableFluid20 8,400 2002000:10:001:24:201.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 1Ͳ8 30#HyborGͲi Pad 37 20,210 4814810:13:001:14:201.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 1Ͳ9 30#HyborGͲi ConditioningPad 100M 0.25 37 16,000 3813854,000 0:10:251:01:191.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 1Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 12,000 28629812,000 0:08:040:50:551.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 1Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 16,000 38141532,000 0:11:140:42:501.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 1Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 16,000 38143248,000 0:11:420:31:361.00 0.25 1.00 0.22 30.00 2.00 2.00 0.15 1Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 10,000 23828140,000 0:07:370:19:541.00 0.25 1.00 0.22 30.00 2.00 2.00 0.15 1Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 8,000 19022936,000 0:06:120:12:171.00 0.25 1.00 0.22 30.00 2.00 3.00 0.15 1Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 6,400 15218632,000 0:05:030:06:051.00 0.25 1.00 0.22 30.00 2.00 3.00 0.15 1Ͳ16 30#HyborGͲiSpacerandDartDrop 37 1,596 38380:01:020:01:021.00 0.25 1.00 0.22 30.00 2.00 3.00 0.15 2Ͳ1 30#HyborGͲi MinifracͲTreatment 37 18,105 4314310:11:391:26:241.00 0.25 1.00 0.22 30.00 2.00 3.00 0.15 2Ͳ2 30#Linear MinifracͲFlush37 13,143 3133130:08:271:14:451.00 30.00 2.00 3.00 0.15 2Ͳ3 ShutͲIn ShutͲIn 1:06:17 2Ͳ4 30#HyborGͲi EstablishStableFluid15 8,400 2002000:13:201:06:171.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ5 30#HyborGͲi Pad 37 9,575 2282280:06:100:52:571.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ6 30#HyborGͲi ConditioningPad 100M 0.25 37 16,000 3813854,000 0:10:250:46:481.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2,600 62652,600 0:01:450:36:231.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 3,270 78856,540 0:02:180:34:381.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 5,230 12514115,690 0:03:500:32:201.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 6,340 15117825,360 0:04:490:28:311.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 6,530 15518729,385 0:05:040:23:411.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 2Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 7,080 16920635,400 0:05:360:18:371.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 2Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 7,190 17121339,545 0:05:470:13:021.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 2Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 7,580 18022945,480 0:06:130:07:141.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 2Ͳ15 30#HyborGͲiSpacerandDartDrop 37 1,596 38380:01:020:01:021.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 3Ͳ1 30#HyborGͲi Pad 37 7,810 1861860:05:021:00:521.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37 16,000 3813854,000 0:10:250:55:511.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2,000 48502,000 0:01:210:45:261.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2,500 60655,000 0:01:450:44:051.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4,000 9510812,000 0:02:560:42:201.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4,850 11513619,400 0:03:410:39:241.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5,000 11914322,500 0:03:530:35:431.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5,410 12915827,050 0:04:170:31:501.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 3Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5,500 13116330,250 0:04:260:27:341.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 3Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5,800 13817534,800 0:04:450:23:081.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 3Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4,000 9512326,000 0:03:200:18:231.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 3Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:15:031.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 3Ͳ13 30#Linear Flush 37 13,874 3303300:08:560:12:301.00 30.00 2.00 3.00 0.15 3Ͳ14 FreezeProtect FreezeProtect 10 1,500 36360:03:340:03:34 3Ͳ15 ShutͲIn ShutͲIn 12/9/24 LiquidAdditives DryAdditives 50Ͳ103Ͳ20889 909746254 Interval 1Moraine@ 20989.08 - 20993.42 ft 138.5 °F"Alpha SleeveInterval 2Moraine@ 20561.76 - 20566.1 ft 138.5 °F"Frac Sleeve 1Interval 3Moraine@ 20108.31 - 20112.65 ft 138.6 °F"Frac Sleeve 2ConocoPhillipsͲ3TͲ608 PlannedDesign 99 CUSTOMER ConocoPhillipsFALSE API BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDE BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(p8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean DesignClean DesignSlurry DesignProp Stage IntervalCLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time Time Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) 12/9/24 LiquidAdditives DryAdditives 50Ͳ103Ͳ20889 909746254 4Ͳ1 ShutͲIn ShutͲIn 1:24:32 4Ͳ2 FreezeProtect PrimeUpPressureTest 5 1,000 24240:04:461:24:32 4Ͳ3 ShutͲIn ShutͲIn 1:19:47 4Ͳ4 30#Linear SpacerandDartDrop 15 1,260 30300:02:001:19:471.00 30.00 2.00 2.00 0.15 4Ͳ5 30#HyborGͲi EstablishStableFluid15 8,400 2002000:13:201:17:471.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ6 30#HyborGͲi Pad 37 7,810 1861860:05:021:04:271.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ7 30#HyborGͲi ConditioningPad 100M 0.25 37 16,000 3813854,000 0:10:250:59:251.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2,000 48502,000 0:01:210:49:001.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2,500 60655,000 0:01:450:47:401.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4,000 9510812,000 0:02:560:45:541.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4,850 11513619,400 0:03:410:42:591.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5,000 11914322,500 0:03:530:39:171.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5,410 12915827,050 0:04:170:35:251.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 4Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5,500 13116330,250 0:04:260:31:081.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 4Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5,800 13817534,800 0:04:450:26:431.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 4Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4,000 9512326,000 0:03:200:21:571.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 4Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:18:371.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 4Ͳ18 30#Linear Flush 37 13,875 3303300:08:560:16:041.00 30.00 2.00 3.00 0.15 4Ͳ19 FreezeProtect FreezeProtect 5 1,500 36360:07:090:07:09 4Ͳ20 ShutͲIn ShutͲInInterval 4Moraine@ 19654.3 - 19658.64 ft 138.6 °F"Frac Sleeve 3ConocoPhillipsͲ3TͲ608 PlannedDesign 100 CUSTOMER ConocoPhillipsFALSE API BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDE BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(p8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean DesignClean DesignSlurry DesignProp Stage IntervalCLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time Time Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) 12/9/24 LiquidAdditives DryAdditives 50Ͳ103Ͳ20889 909746254 5Ͳ1 ShutͲIn ShutͲIn 1:31:29 5Ͳ2 FreezeProtect PrimeUpPressureTest 5 1,000 24240:04:461:31:29 5Ͳ3 ShutͲIn ShutͲIn 1:26:43 5Ͳ4 30#Linear SpacerandDartDrop 15 1,260 30300:02:001:26:431.00 30.00 2.00 2.00 0.15 5Ͳ5 30#Linear DisplaceDarttoSeat 15 13,431 3203200:21:191:24:431.00 30.00 2.00 2.00 0.15 5Ͳ6 30#Linear DFIT 10 1,680 40400:04:001:03:241.00 30.00 2.00 2.00 0.15 5Ͳ7 ShutͲIn ShutͲIn 0:59:24 5Ͳ8 30#HyborGͲi EstablishStableFluid20 8,400 2002000:10:000:59:241.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ9 30#HyborGͲi Pad 37 7,810 1861860:05:020:49:241.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ10 30#HyborGͲi ConditioningPad 100M 0.25 37 16,000 3813854,000 0:10:250:44:221.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2,000 48502,000 0:01:210:33:581.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2,500 60655,000 0:01:450:32:371.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4,000 9510812,000 0:02:560:30:521.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4,850 11513619,400 0:03:410:27:561.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5,000 11914322,500 0:03:530:24:151.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 5Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5,410 12915827,050 0:04:170:20:221.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 5Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5,500 13116330,250 0:04:260:16:051.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 5Ͳ18 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5,800 13817534,800 0:04:450:11:401.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 5Ͳ19 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4,000 9512326,000 0:03:200:06:551.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 5Ͳ20 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:03:341.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 5Ͳ21 30#HyborGͲiSpacerandDartDrop 37 1,596 38380:01:020:01:021.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ1 30#HyborGͲi Pad 37 7,810 1861860:05:020:49:241.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37 16,000 3813854,000 0:10:250:44:221.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.0000 37 2,000 48502,000 0:01:210:33:581.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2,500 60655,000 0:01:450:32:371.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4,000 9510812,000 0:02:560:30:521.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4,850 11513619,400 0:03:410:27:561.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5,000 11914322,500 0:03:530:24:151.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5,410 12915827,050 0:04:170:20:221.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 7Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5,500 13116330,250 0:04:260:16:051.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 7Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5,800 13817534,800 0:04:450:11:401.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 7Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4,000 9512326,000 0:03:200:06:551.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 7Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:03:341.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 7Ͳ13 30#HyborGͲiSpacerandDartDrop 37 1,596 38380:01:020:01:021.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 8Ͳ1 30#HyborGͲi Pad 37 7,810 1861860:05:020:49:241.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37 16,000 3813854,000 0:10:250:44:221.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2,000 48502,000 0:01:210:33:581.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2,500 60655,000 0:01:450:32:371.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.0000 37 4,000 9510812,000 0:02:560:30:521.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4,850 11513619,400 0:03:410:27:561.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5,000 11914322,500 0:03:530:24:151.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5,410 12915827,050 0:04:170:20:221.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 8Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5,500 13116330,250 0:04:260:16:051.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 8Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5,800 13817534,800 0:04:450:11:401.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 8Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4,000 9512326,000 0:03:200:06:551.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 8Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:03:341.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 8Ͳ13 30#HyborGͲiSpacerandDartDrop 37 1,596 38380:01:020:01:021.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 9Ͳ1 30#HyborGͲi Pad 37 7,810 1861860:05:020:49:241.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37 16,000 3813854,000 0:10:250:44:221.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2,000 48502,000 0:01:210:33:581.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2,500 60655,000 0:01:450:32:371.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4,000 9510812,000 0:02:560:30:521.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4,850 11513619,400 0:03:410:27:561.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5,000 11914322,500 0:03:530:24:151.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5,410 12915827,050 0:04:170:20:221.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 9Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5,500 13116330,250 0:04:260:16:051.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 9Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5,800 13817534,800 0:04:450:11:401.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 9Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4,000 9512326,000 0:03:200:06:551.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 9Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:03:341.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 9Ͳ13 30#HyborGͲiSpacerandDartDrop 37 1,596 38380:01:020:01:021.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 10Ͳ1 30#HyborGͲi Pad 37 7,810 1861860:05:020:59:291.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37 16,000 3813854,000 0:10:250:54:271.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2,000 48502,000 0:01:210:44:021.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2,500 60655,000 0:01:450:42:421.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4,000 9510812,000 0:02:560:40:561.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4,850 11513619,400 0:03:410:38:011.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5,000 11914322,500 0:03:530:34:191.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5,410 12915827,050 0:04:170:30:271.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 10Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5,500 13116330,250 0:04:260:26:101.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 10Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5,800 13817534,800 0:04:450:21:451.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 10Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4,000 9512326,000 0:03:200:16:591.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 10Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:13:391.00 0.25 1.00 0.25 30.00 2.00 3.00 0.15 10Ͳ13 30#Linear Flush 37 11,821 2812810:07:360:11:061.00 30.00 2.00 3.00 0.15 10Ͳ14 FreezeProtect FreezeProtect 10 1,470 35350:03:300:03:30 10Ͳ15 ShutͲIn ShutͲInInterval 9Moraine@ 17174.33 - 17178.67 ft 138.6 °F"Frac Sleeve 8Interval 10Moraine@ 16680.58 - 16684.92 ft 138.6 °F"Frac Sleeve 9Interval 5Moraine@ 19199.27 - 19203.61 ft 138.7 °F"Frac Sleeve 4Interval 7Moraine@ 18125.66 - 18130 ft 138.8 °F"Frac Sleeve 6Interval 8Moraine@ 17671.64 - 17675.98 ft 138.7 °F"Frac Sleeve 7ConocoPhillipsͲ3TͲ608 PlannedDesign 101 CUSTOMER ConocoPhillipsFALSE API BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDE BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(p8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean DesignClean DesignSlurry DesignProp Stage IntervalCLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time Time Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) 12/9/24 LiquidAdditives DryAdditives 50Ͳ103Ͳ20889 909746254 11Ͳ1 ShutͲIn ShutͲIn 1:24:35 11Ͳ2 FreezeProtect PrimeUpPressureTest 5 1,000 24240:04:461:24:35 11Ͳ3 ShutͲIn ShutͲIn 1:19:49 11Ͳ4 30#Linear SpacerandDartDrop 15 1,260 30300:02:001:19:491.00 30.00 2.00 2.00 0.15 11Ͳ5 30#Linear DisplaceDarttoSeat 15 10,346 2462460:16:251:17:491.00 30.00 2.00 2.00 0.15 11Ͳ6 30#Linear DFIT 20 1,680 40400:02:001:01:241.00 30.00 2.00 2.00 0.15 11Ͳ7 ShutͲIn ShutͲIn 0:59:24 11Ͳ8 30#HyborGͲi EstablishStableFluid20 8,400 2002000:10:000:59:241.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 11Ͳ9 30#HyborGͲi Pad 37 7,810 1861860:05:020:49:241.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 11Ͳ10 30#HyborGͲi ConditioningPad 100M 0.25 37 16,000 3813854,000 0:10:250:44:221.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 11Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2,000 48502,000 0:01:210:33:581.00 0.25 1.00 0.25 30.00 2.00 2.00 0.15 11Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2,500 60655,000 0:01:450:32:371.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 11Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4,000 9510812,000 0:02:560:30:521.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 11Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4,850 11513619,400 0:03:410:27:561.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 11Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5,000 11914322,500 0:03:530:24:151.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 11Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5,410 12915827,050 0:04:170:20:221.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 11Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5,500 13116330,250 0:04:260:16:051.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 11Ͳ18 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5,800 13817534,800 0:04:450:11:401.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 11Ͳ19 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4,000 9512326,000 0:03:200:06:551.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 11Ͳ20 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:03:341.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 11Ͳ21 30#HyborGͲiSpacerandDartDrop 37 1,596 38380:01:020:01:021.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 12Ͳ1 30#HyborGͲi Pad 37 7,810 1861860:05:020:59:041.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37 16,000 3813854,000 0:10:250:54:031.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2,000 48502,000 0:01:210:43:381.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2,500 60655,000 0:01:450:42:171.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4,000 9510812,000 0:02:560:40:321.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4,850 11513619,400 0:03:410:37:361.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5,000 11914322,500 0:03:530:33:551.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5,410 12915827,050 0:04:170:30:021.00 0.25 1.00 0.27 30.00 2.00 2.00 0.15 12Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5,500 13116330,250 0:04:260:25:461.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 12Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5,800 13817534,800 0:04:450:21:201.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 12Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4,000 9512326,000 0:03:200:16:351.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 12Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:13:151.00 0.25 1.00 0.27 30.00 2.00 3.00 0.15 12Ͳ13 30#Linear Flush 37 11,188 2662660:07:120:10:421.00 30.00 2.00 3.00 0.15 12Ͳ14 FreezeProtect FreezeProtect 10 1,470 35350:03:300:03:30 12Ͳ15 ShutͲIn ShutͲIn 955,451 22,74925,1332,244,000 DesignTotal(gal)DesignTotal(lbs)CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 2,200,000 (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs) 104,899 44,000 InitialDesignMaterialVolume 840.1 210.0 945.0 210.4 28,350.3 1,890.0 2,188.0 141.8 Ͳ ChemicalExcess 1,260 273.0 1,228.5 273.5 36,855.4 2,457.0 2,844.4 184.3 10,440 Ͳ 0.4258 WholeUnitstobeordered 840,112 Ͳ CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Ͳ (gpm) (gpm) (gpm) (gpm) ppm ppm ppm ppm Ͳ MaxAdditiveRate 672.0 168.0 672.0 336.0 20,160.0 1,344.0 2,016.0 100.8 Ͳ MinAdditiveRate FluidType 30#HyborG 30#Linear Seawater FreezeProtect 30#HyborGͲi Ͳ Ͳ Ͳ ProppantType Wanli16/20Ceramic 100M Ͳ Ͳ ͲInterval 12Moraine@ 15690.17 - 15694.51 ft 138.8 °F"Frac Sleeve 11Interval 11Moraine@ 16185.51 - 16189.85 ft 138.7 °F"Frac Sleeve 1013:02:06 ConocoPhillipsͲ3TͲ608 PlannedDesign 102 Customer: Well: Date: Formation: SO#: Tank Type WaterSource Inches Gallons Barrels Temperature(°F) Inches Gallons Barrels 1 Atigan CPF3 85 16,080 383 105 10 1,627 39 2 Wichita CPF3 100 20,160 480 112 10 1,890 45 3 Wichita CPF3 100 20,160 480 114 10 1,890 45 4 Wichita CPF3 93 18,690 445 116 2 378 9 5 Wichita CPF3 101 20,370 485 107 13 2,478 59 6 Wichita CPF3 98 19,740 470 109 13 2,478 59 7 Wichita CPF3 98 19,740 470 105 13 2,478 59 8 Atigan CPF3 102 19,368 461 108 8 1,262 30 9 Wichita CPF3 101 20,370 485 114 11 2,100 50 10 Wichita CPF3 104 21,000 500 112 39 7,392 176 11 Atigan CPF3 100 18,981 452 112 100 18,981 452 12 Atigan CPF3 100 18,981 452 110 100 18,981 452 13 Wichita CPF3 98 19,740 470 106 98 19,740 470 14 Wichita CPF3 99 19,950 475 108 99 19,950 475 15 Wichita CPF3 100 20,160 480 111 100 20,160 480 16 Atigan CPF3 101 19,175 457 115 101 19,175 457 17 Atigan CPF3 102 19,368 461 110 102 19,368 461 18 Atigan CPF3 101 19,175 457 98 13 2,174 52 19 Atigan CPF3 100 18,981 452 116 15 2,540 60 20 Atigan CPF3 102 19,368 461 115 6 897 21 21 Atigan CPF3 102 19,368 461 108 16 2,722 65 22 Wichita CPF3 102 20,580 490 115 13 2,478 59 23 Atigan CPF3 101 19,175 457 113 6 897 21 24 Atigan CPF3 99 18,788 447 112 16 2,722 65 25 Wichita CPF3 101 20,370 485 110 16 3,024 72 Gallons Barrels Gallons Barrels Gallons Barrels 487,839 11,615 177,783 4,233 310,056 7,382 Zones: 1 VolumeNeededforXIntervals(BBL): NumberofTanksNeeded:000 0 TankBottoms(BBL):465 465 465 465 PreͲJobBarrelBottoms General BeginningStrap EndingStrap LocationSummary StartingVolume EndingVolume TotalUsed ConocoPhillips 3TͲ608 12/9/2024 Moraine 909746254 ConocoPhillipsͲ3TͲ608 WaterStraps12.9 103 Customer: Well: Date: Formation: SO#: Tank Type WaterSource Inches Gallons Barrels Temperature(°F) Inches Gallons Barrels 1 Atigan CPF3 104 19,755 470 114 104 19,755 470 2 Wichita CPF3 100 20,160 480 124 15 2,856 68 3 Wichita CPF3 100 20,160 480 123 15 2,856 68 4 Wichita CPF3 100 20,160 480 119 15 2,856 68 5 Wichita CPF3 100 20,160 480 119 52 10,080 240 6 Wichita CPF3 100 20,160 480 120 63 12,390 295 7 Wichita CPF3 104 21,000 500 116 104 21,000 500 8 Atigan CPF3 100 18,981 452 100 18,981 452 9 Wichita CPF3 100 20,160 480 100 20,160 480 10 Wichita CPF3 100 20,160 480 100 20,160 480 11 Atigan CPF3 100 18,981 452 100 18,981 452 12 Atigan CPF3 40 7,102 169 40 7,102 169 13 Wichita CPF3 100 20,160 480 100 20,160 480 14 Wichita CPF3 70 13,860 330 70 13,860 330 15 Wichita CPF3 100 20,160 480 100 20,160 480 16 Atigan CPF3 100 18,981 452 100 18,981 452 17 Atigan CPF3 104 19,755 470 104 19,755 470 18 Atigan CPF3 104 19,755 470 104 19,755 470 19 Atigan CPF3 22 1 22 1 20 Atigan CPF3 22 1 22 1 21 Atigan CPF3 22 1 22 1 22 Wichita CPF3 0 0 0 0 23 Atigan CPF3 22 1 22 1 24 Atigan CPF3 22 1 22 1 25 Wichita CPF3 0 0 0 0 Gallons Barrels Gallons Barrels Gallons Barrels 339,721 8,089 269,959 6,428 69,762 1,661 Zones: 1 VolumeNeededforXIntervals(BBL): NumberofTanksNeeded:000 0 TankBottoms(BBL):449 449 449 449 ConocoPhillips 3TͲ608 12/10/2024 Moraine 909746254 PreͲJobBarrelBottoms General BeginningStrap EndingStrap LocationSummary StartingVolume EndingVolume TotalUsed ConocoPhillipsͲ3TͲ608 WaterStraps12.10 104 Customer: Well: Date: Formation: SO#: Tank Type WaterSource Inches Gallons Barrels Temperature(°F) Inches Gallons Barrels 1 Atigan CPF3 104 19,755 470 114 12 1,992 47 2 Wichita CPF3 102 20,580 490 124 14 2,646 63 3 Wichita CPF3 102 20,580 490 123 13 2,478 59 4 Wichita CPF3 102 20,580 490 119 14 2,646 63 5 Wichita CPF3 102 20,580 490 119 14 2,646 63 6 Wichita CPF3 102 20,580 490 120 10 1,890 45 7 Wichita CPF3 104 21,000 500 116 14 2,646 63 8 Atigan CPF3 100 18,981 452 44 7,873 187 9 Wichita CPF3 104 21,000 500 44 8,400 200 10 Wichita CPF3 100 20,160 480 13 2,478 59 11 Atigan CPF3 100 18,981 452 16 2,722 65 12 Atigan CPF3 102 19,368 461 15 2,540 60 13 Wichita CPF3 93 18,690 445 12 2,268 54 14 Wichita CPF3 93 18,690 445 15 2,856 68 15 Wichita CPF3 102 20,580 490 8 1,512 36 16 Atigan CPF3 100 18,981 452 16 2,722 65 17 Atigan CPF3 104 19,755 470 16 2,722 65 18 Atigan CPF3 104 19,755 470 13 2,174 52 19 Atigan CPF3 102 19,368 461 13 2,174 52 20 Atigan CPF3 102 19,368 461 13 2,174 52 21 Atigan CPF3 102 19,368 461 14 2,357 56 22 Wichita CPF3 102 20,580 490 8 1,512 36 23 Atigan CPF3 70 13,178 314 12 1,992 47 24 Atigan CPF3 70 13,178 314 12 1,992 47 25 Wichita CPF3 70 13,860 330 12 2,268 54 Gallons Barrels Gallons Barrels Gallons Barrels 477,500 11,369 69,681 1,659 407,818 9,710 Zones: 1 VolumeNeededforXIntervals(BBL): NumberofTanksNeeded:000 0 TankBottoms(BBL):455 455 455 455 PreͲJobBarrelBottoms General BeginningStrap EndingStrap LocationSummary StartingVolume EndingVolume TotalUsed ConocoPhillips 3TͲ608 12/11/2024 Moraine 909746254 ConocoPhillipsͲ3TͲ608 WaterStraps12.11 105 Customer: Well: Date: Formation: SO#: Tank Type WaterSource Inches Gallons Barrels Temperature(°F) Inches Gallons Barrels 1 Atigan CPF3 78 14,726 351 114 12 1,992 47 2 Wichita CPF3 98 19,740 470 124 12 2,268 54 3 Wichita CPF3 104 21,000 500 123 43 8,190 195 4 Wichita CPF3 104 21,000 500 119 43 8,190 195 5 Wichita CPF3 104 21,000 500 119 43 8,190 195 6 Wichita CPF3 96 19,320 460 120 43 8,190 195 7 Wichita CPF3 96 19,320 460 116 12 2,268 54 8 Atigan CPF3 96 18,208 434 12 1,992 47 9 Wichita CPF3 104 21,000 500 12 2,268 54 10 Wichita CPF3 104 21,000 500 12 2,268 54 11 Atigan CPF3 104 19,755 470 12 1,992 47 12 Atigan CPF3 12 1,992 47 12 1,992 47 13 Wichita CPF3 66 13,020 310 12 2,268 54 14 Wichita CPF3 15 Wichita CPF3 16 Atigan CPF3 17 Atigan CPF3 18 Atigan CPF3 19 Atigan CPF3 20 Atigan CPF3 21 Atigan CPF3 22 Wichita CPF3 23 Atigan CPF3 24 Atigan CPF3 25 Wichita CPF3 Gallons Barrels Gallons Barrels Gallons Barrels 231,081 5,502 52,068 1,240 179,013 4,262 Zones: 1 VolumeNeededforXIntervals(BBL): NumberofTanksNeeded:000 0 TankBottoms(BBL):458 458 458 458 ConocoPhillips 3TͲ608 12/11/2024 Moraine 909746254 PreͲJobBarrelBottoms General BeginningStrap EndingStrap LocationSummary StartingVolume EndingVolume TotalUsed ConocoPhillipsͲ3TͲ608 WaterStraps12.15 106 Specific Gravity Testing Temperature DissolvedIron (Fe2+) Chloride (ClͲ) Sulfate (SO4 2Ͳ) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH PostͲCrosslink pH Crosslink Bacteria Ͳ °F mg/L mg/L mg/L mg/L mg/L mg/L cP ͲͲ Ͳ (Y/N) BQValue Tank# H2S present? Y/N Hydrometer DigitalThermometer Strip Strip Strip Titration TotalHardness MinusCalcium Titration FANNͲ35 Probe Probe Probe Ͳ Mycometer 1 N 1.020 87.0 2 15,010 800 2,360 440 2,800 25.0 7.40 7.62 8.88 Y 122,193 2 N 1.020 99.0 2 15,010 800 1,880 920 2,800 24.0 7.33 7.27 8.80 Y 27,089 3 N 1.020 97.0 2 16,270 800 2,680 Ͳ80 2,600 25.0 7.35 7.29 8.87 Y 9,666 4 N 1.020 98.0 2 16,270 800 1,920 560 2,480 26.0 7.10 7.13 8.85 Y 1,220 5 N 1.020 96.0 2 15,010 800 2,040 520 2,560 24.0 7.23 7.14 8.87 Y 6,642 6 N 1.020 95.0 2 15,010 800 1,600 880 2,480 25.0 7.13 7.30 8.94 Y 130,680 7 N 1.020 96.0 2 15,010 800 1,600 1,120 2,720 24.0 7.04 7.30 9.26 Y 1,691 8 N 1.020 95.0 2 15,010 800 1,520 1,800 3,320 26.0 7.24 7.34 8.97 Y 8,631 9 N 1.020 92.0 2 15,010 800 1,800 1,560 3,360 25.0 7.10 7.18 8.87 Y 124,924 10 N 1.020 93.0 2 15,010 800 1,280 1,760 3,040 24.0 7.30 7.18 9.00 Y 201,622 11 N 1.020 91.0 2 15,010 800 2,360 320 2,680 26.0 7.77 7.57 8.73 Y 46,319 12 N 1.020 89.0 2 16,270 800 2,240 600 2,840 25.0 7.05 7.19 9.14 Y 143,236 13 N 1.020 88.0 2 16,270 800 1,480 1,320 2,800 26.0 7.11 7.17 9.01 Y 264,224 14 N 1.020 102.0 2 16,270 800 1,480 1,240 2,720 25.0 7.00 7.12 8.78 Y 188,208 15 N 1.020 86.3 2 16,270 800 2,760 80 2,840 26.0 7.00 7.14 8.67 Y 132,235 16 N 1.020 96.0 2 17,640 800 1,240 1,440 2,680 27.0 6.93 7.13 8.91 Y 3,678 17 N 1.020 102.0 2 16,270 800 1,320 1,240 2,560 25.0 6.99 7.13 8.65 Y 258,208 18 N 1.020 102.0 2 16,270 800 1,480 1,200 2,680 25.0 7.05 7.17 8.57 Y 256,719 19 N 1.020 105.0 2 16,270 800 1,360 1,200 2,560 25.0 7.07 7.23 8.62 Y 196,051 20 N 1.020 117.0 2 15,010 800 1,320 1,520 2,840 22.0 7.08 7.14 8.65 Y 184,939 21 N 1.020 120.0 2 15,010 800 1,400 1,400 2,800 21.0 7.15 7.23 8.64 Y 118,156 22 N 1.020 102.0 2 15,010 800 1,920 1,280 3,200 23.0 7.05 7.16 8.71 Y 112,103 23 N 1.020 100.0 2 15,010 800 1,960 1,040 3,000 25.0 7.19 7.15 8.74 Y 232,131 24 N 1.020 108.6 2 15,010 800 2,040 680 2,720 24.0 7.21 7.13 8.88 Y 67,983 25 N 1.020 97.3 2 15,010 800 2,000 1,080 3,080 25.0 7.18 7.09 8.81 Y 945 Average 1.020 2 12,974 800 1,501 837 2,339 24.7 7.16 7.22 8.83 Ͳ 113,580 Maximum 1.020 2 17,640 800 2,760 1,800 3,360 27.0 7.77 7.62 9.26 Ͳ 264,224 Minimum 1.020 2 0 800 0 0 0 21.00 6.93 7.09 8.57 Ͳ 945 Range 0.000 0 17,640 0 2,760 1,800 3,360 6.0 0.84 0.53 0.69 Ͳ 263,279 AlaskaDistrictFieldQC PrejobWaterAnalysisonLocation Company:ConocoPhillips WellName:3TͲ608 WaterSource:CPF3 ConocoPhillipsͲ3TͲ608 WaterAnalysis12.9 107 Specific Gravity Testing Temperature DissolvedIron (Fe2+) Chloride (ClͲ) Sulfate (SO4 2Ͳ) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH PostͲCrosslink pH Crosslink Bacteria Ͳ °F mg/L mg/L mg/L mg/L mg/L mg/L cP ͲͲ Ͳ (Y/N) BQValue Tank# H2S present? Y/N Hydrometer DigitalThermometer Strip Strip Strip Titration TotalHardness MinusCalcium Titration FANNͲ35 Probe Probe Probe Ͳ Mycometer 1 N 1.018 99.6 2 18,010 1,600 1,920 760 2,680 865 2 N 1.018 99.6 2 15,420 1,600 1,520 1,280 2,800 881 3 N 1.017 99.6 2 18,010 1,600 1,680 1,120 2,800 334 4 N 1.017 99.6 2 15,420 1,600 1,760 1,120 2,880 495 5 N 1.018 94.4 2 14,270 1,600 1,760 960 2,720 539 6 N 1.018 94.4 2 14,270 1,600 2,000 800 2,800 41,843 7 N 1.018 94.4 2 14,270 1,600 1,680 1,120 2,800 836 8 Average 1.018 2 15,667 1600 1,760 1023 2,783 29.0 7.26 7.50 8.75 Ͳ 6,542 Maximum 1.018 2 18,010 1,600 2,000 1,280 2,880 30.0 7.32 7.55 8.80 Ͳ 41,843 Minimum 1.017 2 14,270 1,600 1,680 800 2,720 0.00 0.00 0.00 0.00 Ͳ 334 Range 0.001 0 3,740 0 320 480 160 30.0 7.32 7.55 8.80 Ͳ 41,509 AlaskaDistrictFieldQC PrejobWaterAnalysisonLocation Company:ConocoPhillips WellName:3TͲ608 WaterSource:CPF3 28.0 7.32 7.45 8.80 Y 30.0 7.20 7.55 8.70 Y ConocoPhillipsͲ3TͲ608 WaterAnalysis12.10 108 Specific Gravity Testing Temperature DissolvedIron (Fe2+) Chloride (ClͲ) Sulfate (SO4 2Ͳ) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH PostͲCrosslink pH Crosslink Bacteria Ͳ °F mg/L mg/L mg/L mg/L mg/L mg/L cP ͲͲ Ͳ (Y/N) BQValue Tank# H2S present? Y/N Hydrometer DigitalThermometer Strip Strip Strip Titration TotalHardness MinusCalcium Titration FANNͲ35 Probe Probe Probe Ͳ Mycometer 1 N 1.020 105.0 2 18,010 1,600 2,200 800 3,000 598 2 N 1.018 105.0 2 16,660 1,600 2,800 80 2,880 361 3 N 1.018 105.0 2 16,660 1,600 2,080 1,000 3,080 252 4 N 1.020 105.0 2 15,420 1,600 2,600 760 3,360 333 5 N 1.018 105.0 2 15,420 1,600 2,160 1,160 3,320 539 6 N 1.020 100.0 2 15,420 1,600 2,000 1,400 3,400 4,408 17 N 1.020 100.0 2 16,660 1,600 2,600 520 3,120 41,413 18 N 1.020 100.0 2 16,660 1,200 2,320 1,040 3,360 54,721 19 N 1.020 100.0 2 15,420 1,600 2,720 560 3,280 22,178 20 N 1.020 100.0 2 15,420 1,200 2,600 600 3,200 36,435 21 N 1.018 89.2 2 15,420 1,600 2,480 920 3,400 55,569 22 N 1.018 93.2 2 18,010 1,600 2,200 1,480 3,680 79,090 23 N 1.020 91.2 2 15,420 1,600 2,400 1,200 3,600 32,215 24 N 1.018 87.2 2 15,420 1,600 2,000 1,440 3,440 120,448 25 N 1.020 88.7 2 18,010 1,200 2,320 960 3,280 1,336 Average 1.019 2 16,269 1520 2,365 928 3,293 25.7 7.21 7.42 8.80 Ͳ 29,993 Maximum 1.020 2 18,010 1,600 2,800 1,480 3,680 27.0 7.22 7.43 8.90 Ͳ 120,448 Minimum 1.018 2 15,420 1,200 2,000 520 3,120 26.00 7.20 7.42 8.70 Ͳ 252 Range 0.002 0 2,590 400 800 960 560 1.0 0.02 0.01 0.20 Ͳ 120,196 AlaskaDistrictFieldQC PrejobWaterAnalysisonLocation Company:ConocoPhillips WellName:3TͲ608 WaterSource:CPF3 27.0 7.20 7.43 8.70 Y 24.0 7.22 7.42 8.90 Y 26.0 7.20 7.42 8.80 Y ConocoPhillipsͲ3TͲ608 WaterAnalysis12.11 109 Specific Gravity Testing Temperature DissolvedIron (Fe2+) Chloride (ClͲ) Sulfate (SO4 2Ͳ) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH PostͲCrosslink pH Crosslink Bacteria Ͳ °F mg/L mg/L mg/L mg/L mg/L mg/L cP ͲͲ Ͳ (Y/N) BQValue Tank# H2S present? Y/N Hydrometer DigitalThermometer Strip Strip Strip Titration TotalHardness MinusCalcium Titration FANNͲ35 Probe Probe Probe Ͳ Mycometer 1 N 1.018 90.0 2 16,660 800 1,840 960 2,800 148,644 2 N 1.018 90.0 2 16,660 800 1,720 960 2,680 2,085 3 N 1.020 90.0 2 15,420 800 2,000 840 2,840 6,589 4 N 1.018 90.0 2 15,420 800 2,400 480 2,880 5 N 1.020 90.0 2 15,420 800 1,800 800 2,600 6 N 1.020 89.0 2 16,660 800 2,200 320 2,520 7 N 1.020 89.0 2 16,660 800 2,200 320 2,520 8 N 1.020 89.0 2 15,420 800 2,120 560 2,680 9 N 1.020 89.0 2 16,660 800 2,200 320 2,520 10 N 1.020 89.0 2 16,660 800 2,320 200 2,520 11 N 1.020 89.0 2 16,660 800 2,200 320 2,520 Average 1.019 2 16,209 800 2,091 553 2,644 25.0 7.21 7.31 9.29 Ͳ 52,439 Maximum 1.020 2 16,660 800 2,400 960 2,880 26.0 7.23 7.32 9.50 Ͳ 148,644 Minimum 1.018 2 15,420 800 1,800 200 2,520 26.00 7.18 7.30 9.50 Ͳ 2,085 Range 0.002 0 1,240 0 600 760 360 0.0 0.05 0.02 0.00 Ͳ 146,559 24.0 7.23 7.32 9.08 Y 26.0 7.18 7.30 9.50 Y WellName:3TͲ608 WaterSource:CPF3 AlaskaDistrictFieldQC PrejobWaterAnalysisonLocation Company:ConocoPhillips ConocoPhillipsͲ3TͲ608 WaterAnalysis12.5 110 Linear Linear XL XL XL Lip time Linear Linear XL XL XL Lip time Interval Stage Visc pH Temp °F pH min Interval Stage Visc pH Temp °F pH min 1 Pad 22 8.7 89 8.9 0 12 Pad 28 8.7 79 8.78 0 .25# 19 8.8 89 9 0 23 Avg Linear Visc .25# 27 Avg Linear Visc 1.00# 24 8.8 89 9.1 0 91.0 Avg XLTemp 1.00# 27 8.7 75 8.77 0 75.4 Avg XLTemp 2.00# 22 8.88 97 9.1 0 9.0 Avg XL pH 2.00# 8.8 Avg XL pH 3.00# 24 8.9 96 9.2 0 3.00# 27 8.75 74 8.77 0 4.00# 25 8.9 90 8.9 0 4.00# 4.50# 24 9 89 8.8 0 4.50# 27 8.9 74 8.8 0 5.00# 24 8.9 89 8.8 0 5.00# 5.50# 25 8.7 75 8.86 0 6.00# 6.50# 7.00# 27 8.9 79 8.8 0 2 Pad 24 8.4 72 8.5 0 13 Pad .25# 30 8.5 70 8.5 0 0.25# 1.00# 28 8.6 69 8.5 0 1.00# 2.00# 27 8.9 80 8.8 0 28 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 27 8.9 80 8.8 0 74.5 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 27 8.9 80 8.9 0 8.7 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50#4.50# 5.00# 29 8.8 70 8.8 0 5.00# 5.50#5.50# 6.00# 28 8.8 75 8.88 0 6.00# 6.50# 7.00# 3 Pad 28 8.8 75 8.88 0 14 Pad .25#0.25# 1.00# 29 8.8 95 8.8 0 1.00# 2.00# 28 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 28 8.8 94 8.81 0 84.8 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 8.8 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50# 29 8.9 89 8.8 0 4.50# 5.00#5.00# 5.50# 26 8.9 74 8.8 0 5.50# 6.00#6.00# 6.50# 29 8.8 82 8.8 0 6.50# 7.00#7.00# 4 Pad 26 8.5 98 8.5 0 14 Pad .25#0.25# 1.00# 29 8.8 111 8.8 0 1.00# 2.00# 28 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 28 8.9 120 8.71 0 101.3 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 8.7 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50# 28 8.9 89 8.75 0 4.50# 5.00#5.00# 5.50# 28 8.9 90 8.8 0 5.50# 6.00#6.00# 6.50# 28 9 100 8.8 0 6.50# 7.00#7.00# 5 Pad 29 8.7 90 8.5 0 15 Pad .25#0.25# 1.00# 30 8.8 95 8.8 0 1.00# 2.00# 29 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 28 8.8 98 8.8 0 93.5 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 8.8 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50# 29 8.8 89 8.9 0 4.50# 5.00#5.00# 5.50# 28 8.8 94 8.87 0 5.50# 6.00#6.00# 6.50# 28 8.8 95 8.8 0 6.50# 7.00#7.00# 7 Pad 28 8.8 95 8.8 0 16 Pad .25#0.25# 1.00# 28 8.89 98 8.81 0 1.00# 2.00# 28 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 25 9 89 8.82 0 89.0 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 8.8 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50# 27 9.1 82 8.8 0 4.50# 5.00#5.00# 5.50# 29 9.00 85 8.90 0 5.50# 6.00#6.00# 6.50# 28 9.1 85 8.88 0 6.50# 7.00#7.00# 8 Pad 27 9.1 83 8.81 0 17 Pad .25#0.25# 1.00# 32 8.8 82 8.79 0 1.00# 2.00# 30 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 32 8.8 82 8.75 0 83.0 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 8.8 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50# 29 9 87 8.87 0 4.50# 5.00#5.00# 5.50# 30 9.1 89 8.81 0 5.50# 6.00#6.00# 6.50# 29 8.88 75 8.77 0 6.50# 7.00#7.00# 9 Pad 28 9.3 91 8.8 0 18 Pad .25#0.25# 1.00# 27 9.43 92 9 0 1.00# 2.00# 27 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 25 8.79 90 8.72 0 92.5 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 8.8 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50# 27 8.8 95 8.84 0 4.50# 5.00#5.00# 5.50# 26 8.8 92 8.82 0 5.50# 6.00#6.00# 6.50# 28 8.8 95 8.78 0 6.50# 7.00#7.00# 10 Pad 26 8.6 85 8.76 0 19 Pad .25#0.25# 1.00# 24 8.9 93 8.76 0 1.00# 2.00# 27 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 28 8.9 95 8.79 0 91.3 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 8.8 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50# 27 8.91 89 8.82 0 4.50# 5.00#5.00# 5.50# 28 8.88 93 8.75 0 5.50# 6.00#6.00# 6.50# 28 8.9 93 8.79 0 6.50# 7.00#7.00# 11 Pad 28 8.46 75.7 8.4 0 20 Pad .25#0.25# 1.00# 28 8.42 70 8.38 0 1.00# 2.00# 28 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 26 8.7 86 8.6 0 80.1 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 8.6 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50# 28 8.7 90 8.65 0 4.50# 5.00#5.00# 5.50# 28 8.8 80 8.7 0 5.50# 6.00#6.00# 6.50# 27 8.7 79 8.6 0 6.50# 7.00#7.00# Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Customer:Conoco Phillips Wellname & #:3T-608 Date:December 9, 2024 ConocoPhillipsͲ3TͲ608 RealͲTimeQC 111 SeqNo. Time ActivityCode Comment JobSlurryVol TreatingPressureTreatingPressure@Pump SlurryRate TubingGaugeBHPres 1 05:59:38(12/09/24) Other CrewArrivedonLocation ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 2 6:29:41 PreͲJobSafetyMeetingPreͲJobSafetyMeeting ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 3 6:58:03 Other CrewBeginsFunctionTestingEquipment ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 4 7:14:40 StartJob StartingJob 0 0 0 0 0 5 07:14:40(12/09/24) NextTreatment TreatmentInterval10 0 0 0 0 6 7:27:52 NextStage ShutͲIn 0 156 10 0 2229 7 7:44:37 Other LeakonWellhead 0 0 0 0 2229 8 7:51:05 Other BucketTestADP 0 23 8 0 2229 9 8:08:32 Other BucketTestBlender 0 5 12 0 2229 10 8:40:40 Other HighPressureSealReplaced 0 6 13 0 2229 11 8:42:54 Other PrimePumps 0 10 38 0 2229 12 8:57:11 PressureTest ePRVͲPrimaryTubing 0 225 237 0 2229 13 8:59:25 PressureTest ePRVͲPrimaryIA 0 604 632 0 2229 14 9:02:02 PressureTest ePRVͲSecondaryTubing 0 564 475 0 2229 15 9:03:33 PressureTest ePRVͲSecondaryIA 0 735 808 0 2229 16 9:07:07 PressureTest PressureTestͲGlobal 0 427 141 0 2229 17 9:07:37 PressureTest PressureTestͲLocal 0 411 141 0 2229 18 9:09:37 Other LeakonChiksan 0 1139 1175 0 2229 19 9:35:55 PrimePumps PrimePumpsͲAgain 0 43 71 0 2229 20 9:55:50 PressureTest PressureTestͲMax 0 9493 9591 0 2229 21 10:00:51 PressureTest PressureTestͲPass 0 9343 9432 0 2229 22 10:03:08 Other StartMixingGel 0 97 117 0 2229 23 10:11:35 NextStage ShutͲIn 0 52 46 0 2323 24 10:23:25 OpenWell OpenWell 0 393 387 0 2491 25 10:23:29 NextStage DFIT 0 388 389 0 2513 26 10:24:39 Other StartDFIT 0.44 775 844 1.3 3005 27 10:26:10 NextStage ShutͲIn 8.39 1833 1915 9.8 3690 28 10:29:00 ISIP ISIP 34.81 730 788 0 3145 29 10:36:28 Other BringOnChemicalswhilewaitingforDecline 34.81 588 612 0 2900 30 10:41:10 Other LoadDarts 34.81 513 536 0 2788 31 11:12:12 NextStage StepRateTest 34.84 415 365 0 2653 32 11:12:24 OpenWell OpenWell 34.84 380 345 0 2651 33 11:13:57 Other Step1 35.7 874 956 1.2 3289 34 11:15:01 Other Step237.6 1040 1066 1.9 3362 35 11:16:17 Other Step3 41.1 1096 1133 3 3417 36 11:17:33 Other Step4 45.93 1163 1204 4 3468 37 11:18:51 Other Step5 52.41 1238 1281 5.2 3505 38 11:19:52 Other Step6 58.4 1306 1354 6.1 3538 39 11:21:06 Other Step7 66.83 1409 1463 7 3585 40 11:22:21 Other Step8 76.6 1549 1607 8 3658 41 11:23:32 Other Step9 86.89 1685 1745 9 3726 42 11:24:41 Other Step10 98.05 1824 1889 10 3804 43 11:26:54 NextStage EstablishStableFluid 124.94 2496 2557 14.8 4248 44 11:34:05 NextStage Pad 265.42 2880 2982 20.3 4644 45 11:34:06 StartPad StartPad 265.76 2878 2980 20.3 4644 46 11:38:17 Other DroppingRatetoHelpwithPrime 393.73 3249 3374 34.8 4547 47 11:44:13 Other WaterTankManifoldValveTroubleshoot 566.91 3022 3171 31.1 4395 48 11:49:28 NextStage ConditioningPad 746.87 3409 3556 37 4630 49 11:59:37 NextStage ProppantLadenFluid 1122.82 3444 3609 37 4606 50 12:07:45 NextStage ProppantLadenFluid 1423.05 3649 3818 36.9 4721 51 12:18:59 NextStage ProppantLadenFluid 1836.41 3557 3734 36.8 4721 52 12:19:26 Other LostPrimeonBlenderͲTankManagement 1852.95 3553 3730 36.7 4721 53 12:31:57 NextStage ProppantLadenFluid 2266.01 3548 3731 36.8 4721 54 12:39:35 NextStage ProppantLadenFluid 2544.86 3676 3878 36.7 4721 55 12:45:49 NextStage ProppantLadenFluid 2773.47 3747 3945 36.5 4721 56 12:52:42 NextStage Spacer 3025.26 3864 4035 37.1 4721 57 12:53:32 Other DropDartforInterval02 3055.6 4032 4186 37.2 4721 58 12:53:44(12/09/24) NextTreatment TreatmentInterval2 3063.06 4124 4288 37.2 4721 59 12:53:44 NextStage MinifracͲTreatment 3063.68 4125 4288 37.2 4721 60 12:53:47 StartMinifrac StartMinifrac 3064.92 4131 4299 37.2 4721 61 13:00:32 Other SlowDownforDart 3316.23 3561 3713 37.3 4721 62 13:02:11 BallonSeat DartonSeat 3349.34 2733 2862 11.3 4721 63 13:02:29 BreakFormation BreakFormation 3352.74 5986 6114 11.4 4721 64 13:08:29 NextStage MinifracͲFlush 3497.63 3739 3898 36.4 4721 65 13:08:29 StartFlush StartFlush 3497.63 3739 3898 36.4 4721 66 13:17:57 NextStage ShutͲIn 3834.59 1228 1261 0 4721 67 13:17:57 ISIP ISIP 3834.59 1236 1271 0 4721 68 13:22:55 ShutͲInPressure@5Minutes ShutͲInPressure@5Minutes 3834.59 1015 1040 0 4721 69 13:27:54 ShutͲInPressure@10Minutes ShutͲInPressure@10Minutes 3834.59 885 914 0 4721 70 13:32:51 ShutͲInPressure@15Minutes ShutͲInPressure@15Minutes 3834.59 748 776 0 4721 71 13:44:17 Other ResetIFS 3834.59 507 535 0 4721 72 13:44:42 Pause SuspendingJob 3834.59 0 0 0 0 73 13:48:54 Resume ResumingJob 3834.59 5 5 0 36 74 14:12:39 NextStage EstablishStableFluid 3834.59 870 897 0 3078 75 0.592233796 OpenWell OpenWell 3834.59 867 895 0 3077 76 14:21:34 NextStage Pad 3979.83 2779 2877 21.3 4295 77 14:28:27 NextStage ConditioningPad 4207.8 3956 4117 36.9 4840 78 14:39:32 NextStage ProppantLadenFluid 4605.08 3819 3996 36.2 4972 79 14:41:19 NextStage ProppantLadenFluid 4669.62 3734 3914 36.2 4918 80 14:43:39 NextStage ProppantLadenFluid 4753.7 3615 3795 36.1 4864 81 14:47:29 NextStage ProppantLadenFluid 4894.48 3615 3802 37 4882 82 14:52:16 NextStage ProppantLadenFluid 5070.29 3726 3932 36.8 5029 83 14:57:19 NextStage ProppantLadenFluid 5256.45 3913 4139 36.7 5172 84 15:02:54 NextStage ProppantLadenFluid 5460.78 3989 4210 36.8 5274 85 15:08:37 NextStage ProppantLadenFluid 5671.14 4056 4274 36.7 5337 86 15:16:26 NextStage Spacer 5955.31 3892 4129 33.3 5239 87 15:17:35 DropBall DropDartforInterval03 5997.13 4524 4697 37.2 5496 88 15:17:45(12/09/24) NextTreatment TreatmentInterval3 6003.34 4539 4716 37.2 5497 89 15:17:45 NextStage Pad 6003.96 4539 4717 37.2 5497 90 15:22:49 NextStage ConditioningPad 6191.97 4053 4203 37.3 5124 91 15:24:35 Other SlowDownForDart 6257.86 3635 3769 37.3 4779 92 15:27:07 BallonSeat DartonSeat 6296.38 3049 3209 12.5 4401 93 15:27:22 BreakFormation BreakFormation 6299.49 6086 6223 12.4 7617 94 15:37:06 NextStage ProppantLadenFluid 6579.19 4016 4187 37.2 5040 95 15:38:23 NextStage ProppantLadenFluid 6627.45 3926 4108 37.1 5089 96 15:40:07 NextStage ProppantLadenFluid 6691.03 3915 4102 37 5177 97 15:43:02 NextStage ProppantLadenFluid 6798.58 3752 3947 36.9 5071 98 15:46:43 NextStage ProppantLadenFluid 6934.13 3775 3983 36.8 5124 99 15:49:38 Other DroppedRateForBlenderSuction 7041.61 3803 4009 36.7 5171 100 15:50:39 NextStage ProppantLadenFluid 7075.72 3668 3885 33.3 5101 101 15:54:59 NextStage ProppantLadenFluid 7232.11 3908 4114 36.5 5257 102 15:59:25 NextStage ProppantLadenFluid 7394.24 4099 4325 36.4 5406 103 16:04:14 NextStage ProppantLadenFluid 7568.75 4085 4306 36.3 5364 104 16:05:14 Other Pump137Cavitating 7605.03 3897 4155 35.8 5350 105 16:07:53 NextStage ProppantLadenFluid 7692.46 3574 3762 30.4 5063 106 16:12:49 NextStage Flush 7851.21 3982 4143 32.8 5297 107 16:12:49 StartFlush StartFlush 7851.76 4002 4143 32.8 5299 108 16:23:21 ISIP ISIP 8181.56 1344 1372 0 3390 109 17:23:21 NextStage Other 8181.56 1502 1559 0 3698 110 18:23:21 ShutͲInPressure@5Minutes ShutͲInPressure@5Minutes 8181.56 61 112 0 3352 111 19:23:21 ShutͲInPressure@10Minutes ShutͲInPressure@10Minutes 8181.56 155 238 0 3295 112 20:23:21 ShutͲInPressure@15Minutes ShutͲInPressure@15Minutes 8181.56 Ͳ7 32 0 3252 EventLog12.9 ConocoPhillipsͲ3TͲ608 EventLog12.9 112 SeqNo. Time ActivityCode Comment JobSlurryVol TreatingPressureTreatingPressure@Pump SlurryRate TubingGaugeBHPres 1 05:59:22(12/10/24) Other CrewArrivedonLocation ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 2 6:30:25 PreͲJobSafetyMeetingPreͲJobSafetyMeeting ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 3 6:44:23 Other WaitingonWater ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 4 6:56:56 StartJob StartingJob 0 0 0 0 0 1 06:56:56(12/10/24) NextTreatment TreatmentInterval100000 5 7:16:52 Other BucketTestBlender 0 Ͳ33 Ͳ6 0 2427 4 08:44:02(12/10/24) NextTreatment TreatmentInterval40Ͳ33 Ͳ7 0 2420 6 9:23:46 Other FloodwithBrine 0 Ͳ34 Ͳ7 0 2416 7 9:26:43 Other BucketTestADP 0 Ͳ33 Ͳ3 0 2416 8 9:29:01 Other HydraulicLeakonDABlockontheBlender 0 99 106 0 2416 9 9:53:33 PrimePumps PrimePumps 0 18 20 0 2414 10 10:05:54 PressureTest ePRVͲPrimaryTubing 0 449 504 0 2413 11 10:08:42 PressureTest ePRVͲPrimaryIA 0 490 493 0 2413 12 10:11:38 PressureTest ePRVͲSecondaryTubing 0 453 499 0 2412 13 10:13:35 PressureTest ePRVͲSecondaryIA 0 325 383 0 2412 14 10:15:22 PressureTest PressureTestͲGlobal 0 284 289 0 2412 15 10:16:03 PressureTest PressureTestͲLocals 0 459 509 0 2412 16 10:21:48 PressureTest PressureTestͲMax 0 9528 9595 0 2412 17 10:26:49 PressureTest PressureTestͲPass 0 9399 9452 0 2411 18 10:32:32 Other WaitingonWater 0 25 32 0 2411 19 11:48:18 Other BringonChemicals 0 20 30 0 2405 20 12:08:17 Other IssuesOpeningTopSwabValve 0 23 27 0 2404 21 12:38:54 OpenWell OpenWell 0 552 537 0 2561 22 12:41:05 Other ADPComputerTroubleshooting 5.09 1910 1957 5.9 3870 23 12:51:27 DropBall DropDartforInterval4 32.1 2703 2749 14.5 4388 24 13:04:56 StartPad StartPad 230.65 2464 2571 14.8 4248 25 13:08:17 Other SlowDownForDart 280.27 2711 2840 14.8 4211 26 13:11:34 BallonSeat DartonSeat 321.06 2757 2922 11.6 3972 27 13:11:50 AlarmDelta StageAtTopPerf=4 324.15 5882 6049 11.6 7085 28 13:11:51 BreakFormation BreakFormation 324.35 6107 6281 11.6 7397 29 13:14:31 AlarmDelta StageAtTopPerf=5 367.5 5730 5918 24.7 6913 30 13:21:18 AlarmDelta StageAtTopPerf=6 553.62 5257 5426 33 6202 31 13:26:29 AlarmDelta StageAtTopPerf=7 739.58 5039 5196 36.8 6043 32 13:36:33 AlarmDelta StageAtTopPerf=8 1108.96 3956 4128 36.7 5248 33 13:37:55 AlarmDelta StageAtTopPerf=9 1159.1 3929 4114 36.7 5207 34 13:39:40 AlarmDelta StageAtTopPerf=10 1223.25 3898 4077 36.7 5180 35 13:42:36 AlarmDelta StageAtTopPerf=11 1330.85 3933 4124 36.7 5188 36 13:47:05 AlarmDelta StageAtTopPerf=12 1495.07 3990 4188 36.6 5232 37 13:50:48 AlarmDelta StageAtTopPerf=13 1632.19 4088 4289 36.9 5311 38 13:51:59 Other Pump043PowerEndHose 1676.16 4113 4312 37.1 5302 39 13:54:44 Other Pump137BadValves 1769.92 3907 4091 33.4 5234 40 13:55:10 AlarmDelta StageAtTopPerf=14 1784.51 3675 3936 31.9 5108 41 13:58:28 Other Pump563BadValves 1888.5 3738 3932 31.5 5149 42 14:00:15 AlarmDelta StageAtTopPerf=15 1943.78 3727 3939 31.4 5157 43 14:04:00 StartFlush StartFlush 2061.36 3775 3917 31.7 5185 44 14:05:37 AlarmDelta StageAtTopPerf=16 2115.79 4241 4438 34.3 5351 45 14:08:23 Other Pump621DroppedͲPinholeLeakonSuctionManifold 2210.56 3300 3528 28.6 5004 46 14:09:23 AlarmDelta StageAtTopPerf=17 2235.48 3274 3443 24.5 4847 47 14:15:41 ISIP ISIP 2384.77 1380 222 0 3385 48 14:20:15 AlarmDelta StageAtTopPerf=18 2385.84 17 67 2.8 3307 49 14:20:40 ShutͲInPressure@5Minutes ShutͲInPressure@5Minutes 2386.88 37 74 2.4 3303 50 14:25:38 ShutͲInPressure@10Minutes ShutͲInPressure@10Minutes 2387.94 196 258 0 3261 51 14:30:36 ShutͲInPressure@15Minutes ShutͲInPressure@15Minutes 2387.94 0 28 0 3220 EventLog12.10 ConocoPhillipsͲ3TͲ608 EventLog12.10 113 SeqNo. Time ActivityCode Comment JobSlurryVol TreatingPressureTreatingPressure@Pump SlurryRate TubingGaugeBHPres 1 06:00:39(12/11/24) Other CrewArrivesonLocation ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 2 6:28:25 SafetyMeetingͲPreJob SafetyMeetingͲPreJob ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 3 6:50:04 Other CrewBeginsFunctionTestingEquipment ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 4 6:54:57 StartJob StartingJob 0 0 0 0 0 1 06:54:57(12/11/24) NextTreatment TreatmentInterval100000 5 6:55:16 Other BucketTestADP 0.81 Ͳ2 Ͳ42.70 6 6:59:37 Other BucketTestBlender 10.03 Ͳ2 Ͳ4 0 2432 7 7:04:09 Other WaitingonVacTruck10.03 Ͳ3 Ͳ3 0 2432 5 08:33:26(12/11/24) NextTreatment TreatmentInterval5 10.03 0 Ͳ2 0 2426 8 9:08:17 PrimePumps PrimePumps 10.03 0 Ͳ2 0 2423 9 9:29:33 PressureTest ePRVͲPrimaryTubing 10.03 493 518 0 2422 10 9:31:17 Other ePRVͲPrimaryIA 10.03 542 530 0 2422 11 9:33:21 PressureTest ePRVͲSecondaryTubing 10.03 566 530 0 2421 12 9:34:54 PressureTest ePRVͲSecondaryIA 10.03 581 559 0 2421 13 9:36:11 PressureTest PressureTestͲGlobal 10.03 579 242 0 2421 14 9:36:24 PressureTest PressureTestͲLocals 10.03 578 242 0 2421 15 9:43:12 PressureTest PressureTest 10.03 9541 9599 0 2421 16 9:48:19 PressureTest PressureTestͲPass 10.03 9372 9408 0 2420 17 10:22:42 OpenWell OpenWell 11.89 638 560 0 2650 18 10:26:30 DropBall DropDartforInterval05 41.9 3659 3744 14.8 5365 19 10:42:52 Other SlowDownForDart 286.1 2775 2836 15 4580 20 10:45:36 BallonSeat DartonSeat 320.21 2340 2411 12.1 4264 21 10:45:50 BreakFormation BreakFormation 323.24 5639 5705 12.1 7488 22 10:46:36 AlarmDelta StageAtTopPerf=3 331.73 3733 3764 9.7 5653 23 10:46:41 Other StartDFIT 332.54 3735 3781 9.7 5690 24 10:46:49 AlarmDelta StageAtTopPerf=4 333.84 3755 3830 9.8 5741 25 10:49:51 AlarmDelta StageAtTopPerf=5 364.44 3261 3294 10.1 5155 26 10:50:37 ISIP ISIP 371.29 2115 2123 0 4265 27 10:55:40 ShutͲInPressure@5Minutes ShutͲInPressure@5Minutes 371.29 1266 1288 0 3360 28 11:00:36 ShutͲInPressure@10Minutes ShutͲInPressure@10Minutes 371.29 1105 1125 0 3286 29 11:05:35 ShutͲInPressure@15Minutes ShutͲInPressure@15Minutes 371.29 936 954 0 3237 30 11:10:09 OpenWell OpenWell 371.29 1069 1059 0 3237 31 11:21:07 StartPad StartPad 545.24 3686 3774 20.4 5439 32 11:25:05 AlarmDelta StageAtTopPerf=6 654.57 4668 4824 34.7 5819 33 11:26:09 AlarmDelta StageAtTopPerf=8 693.51 4821 4972 36.9 5859 34 11:30:51 AlarmDelta StageAtTopPerf=9 866.94 4833 4972 36.9 5914 35 11:35:55 AlarmDelta StageAtTopPerf=10 1054.3 4311 4454 37 5486 36 11:46:56 AlarmDelta StageAtTopPerf=11 1459.98 3903 4068 36.8 5217 37 11:48:19 AlarmDelta StageAtTopPerf=12 1510.82 3974 4141 36.7 5262 38 11:50:05 AlarmDelta StageAtTopPerf=13 1575.68 4032 4222 36.7 5334 39 11:53:01 AlarmDelta StageAtTopPerf=14 1683.29 4090 4272 36.6 5374 40 11:56:42 AlarmDelta StageAtTopPerf=15 1818.31 4078 4255 36.7 5361 41 11:58:35 Other BinSwaponMover 1887.31 4065 4249 36.6 5370 42 12:00:36 AlarmDelta StageAtTopPerf=16 1961.36 4136 4306 36.6 5354 43 12:04:52 AlarmDelta StageAtTopPerf=17 2117.16 3813 3961 34.7 5183 44 12:09:26 AlarmDelta StageAtTopPerf=18 2274.65 3999 4238 35.5 5375 45 12:14:06 DropBall DropDartforInterval7 2445.19 4647 4784 37.3 5591 7 12:14:10(12/11/24) NextTreatment TreatmentInterval7 2447.69 4677 4782 37.3 5594 46 12:14:11 AlarmDelta StageAtTopPerf=19 2448.93 4698 4786 37.3 5594 47 12:15:03 Other Pump670ShutOffforMechanicalIssue 2481.22 4293 4461 36.7 5656 48 12:17:43 AlarmDelta StageAtTopPerf=20 2559.18 3818 3966 29.5 5107 49 12:21:14 Other SlowDownForDart 2683.5 3720 3851 37.2 4912 50 12:22:47 AlarmDelta StageAtTopPerf=21 2705.98 2887 3000 11.8 4406 51 12:23:21 BallonSeat DartonSeat 2712.5 2903 3018 11.9 4415 52 12:23:36 BreakFormation BreakFormation 2715.45 6073 6225 11.7 7830 53 12:25:59 AlarmDelta StageAtTopPerf=1 2752.98 3598 3681 23.5 5064 54 12:31:25 AlarmDelta StageAtTopPerf=2 2940.09 3861 3978 37 5000 55 12:43:29 AlarmDelta StageAtTopPerf=3 3386.78 3235 3379 36.8 4586 56 12:44:50 AlarmDelta StageAtTopPerf=4 3436.46 3290 3438 36.8 4628 57 12:46:37 AlarmDelta StageAtTopPerf=5 3502.02 3327 3477 36.8 4668 58 12:49:35 AlarmDelta StageAtTopPerf=6 3611.05 3396 3554 36.7 4724 59 12:53:19 AlarmDelta StageAtTopPerf=7 3748.03 3453 3605 36.6 4786 60 12:57:12 AlarmDelta StageAtTopPerf=8 3890.16 3516 3674 36.6 4845 61 13:01:29 AlarmDelta StageAtTopPerf=9 4046.86 3598 3757 36.6 4925 62 13:05:56 AlarmDelta StageAtTopPerf=10 4209.45 3749 3908 36.5 5042 63 13:10:38 DropBall DropDartforInterval08 4379.73 4171 4305 37.1 5165 8 13:10:39(12/11/24) NextTreatment TreatmentInterval8 4380.35 4175 4311 37.1 5156 64 13:10:40 AlarmDelta StageAtTopPerf=11 4380.96 4177 4311 37.1 5159 65 13:13:53 AlarmDelta StageAtTopPerf=12 4501.05 4584 4724 37.1 5745 66 13:16:39 Other SlowDownForDart 4603.27 2592 2756 36.7 4519 67 13:18:50 AlarmDelta StageAtTopPerf=13 4632.01 2518 2632 11.9 3983 68 13:19:01 BallonSeat DartonSeat 4634.01 2535 2642 11.9 3993 69 13:19:17 BreakFormation BreakFormation 4637.37 6118 6264 11.8 7477 70 13:21:59 AlarmDelta StageAtTopPerf=1 4678.06 2848 2936 23.6 4251 71 0.560648148 AlarmDelta StageAtTopPerf=2 4864.98 3365 3491 37.2 4386 72 13:37:53 AlarmDelta StageAtTopPerf=3 5255.24 3434 3597 36.8 4613 73 13:39:13 AlarmDelta StageAtTopPerf=4 5304.22 3482 3640 36.8 4650 74 13:40:59 AlarmDelta StageAtTopPerf=5 5369.08 3486 3661 36.7 4675 75 13:43:54 AlarmDelta StageAtTopPerf=6 5476.09 3548 3709 36.6 4731 76 13:47:32 AlarmDelta StageAtTopPerf=7 5609.29 3581 3753 36.6 4792 77 13:51:22 AlarmDelta StageAtTopPerf=8 5749.67 3603 3780 36.6 4804 78 13:55:38 AlarmDelta StageAtTopPerf=9 5905.65 3642 3817 36.5 4851 79 14:00:03 AlarmDelta StageAtTopPerf=10 6066.81 3652 3814 36.5 4891 80 14:04:50 AlarmDelta StageAtTopPerf=11 6242.04 3983 4112 37.1 5010 9 14:05:05(12/11/24) NextTreatment TreatmentInterval9 6251.32 4053 4180 37.1 5025 81 14:05:18 DropBall DropDartforInterval9 6259.36 4126 4253 37.1 5039 82 14:07:57 AlarmDelta StageAtTopPerf=12 6357.75 3974 4096 37.2 5128 83 14:10:47 Other SlowDownForDart 6462.53 3298 3433 37.3 4441 84 14:13:09 BallonSeat DartonSeat 6495.93 2516 2631 11.9 3951 85 14:13:23 BreakFormation BreakFormation 6498.71 5480 5613 11.8 7075 86 14:13:47 AlarmDelta StageAtTopPerf=13 6503.61 3084 3142 11.8 4460 87 14:15:58 AlarmDelta StageAtTopPerf=1 6542.96 4248 4350 28.9 5654 88 14:21:11 AlarmDelta StageAtTopPerf=2 6728.91 3363 3485 37.1 4449 89 14:32:16 AlarmDelta StageAtTopPerf=3 7139.13 3017 3170 36.7 4375 90 14:33:33 AlarmDelta StageAtTopPerf=4 7186.29 3056 3208 36.7 4412 91 14:35:17 AlarmDelta StageAtTopPerf=5 7249.95 3086 3250 36.7 4436 92 14:38:14 AlarmDelta StageAtTopPerf=6 7358.03 3177 3337 36.6 4502 93 14:41:56 AlarmDelta StageAtTopPerf=7 7493.38 3238 3405 36.5 4552 94 14:45:50 AlarmDelta StageAtTopPerf=8 7635.99 3301 3450 36.5 4610 95 14:50:09 AlarmDelta StageAtTopPerf=9 7793.5 3351 3515 36.5 4640 96 14:54:36 AlarmDelta StageAtTopPerf=10 7955.09 3449 3605 36.4 4731 97 14:59:21 AlarmDelta StageAtTopPerf=11 8128.68 3846 3985 37.1 4846 98 14:59:41 DropBall DropDartforInterval10 8141.04 3952 4090 37.1 4864 10 14:59:44(12/11/24) NextTreatment TreatmentInterval10 8142.9 4026 4159 37.1 4877 99 15:02:28 AlarmDelta StageAtTopPerf=12 8244.19 3921 4037 37 5001 100 15:07:22 BallonSeat DartonSeat 8378.43 2429 2556 12.1 3858 101 15:07:36 BreakFormation BreakFormation 8381.23 5628 5766 12 7140 102 15:07:59 AlarmDelta StageAtTopPerf=13 8385.79 3963 4090 11.9 5500 103 15:10:05 AlarmDelta StageAtTopPerf=1 8426.75 4195 4289 29 5530 104 15:15:22 AlarmDelta StageAtTopPerf=2 8616.46 3780 3896 37.2 4821 105 15:25:46 AlarmDelta StageAtTopPerf=3 9002.46 3251 3392 36.8 4522 106 15:27:06 AlarmDelta StageAtTopPerf=4 9051.58 3254 3409 36.8 4502 107 15:28:50 AlarmDelta StageAtTopPerf=5 9115.36 3279 3436 36.8 4486 108 15:31:45 AlarmDelta StageAtTopPerf=6 9222.73 3398 3571 36.8 4555 109 15:35:27 AlarmDelta StageAtTopPerf=7 9358.77 3504 3666 36.8 4615 110 15:39:20 AlarmDelta StageAtTopPerf=8 9501.3 3529 3705 36.7 4679 111 15:43:34 AlarmDelta StageAtTopPerf=9 9656.43 3562 3731 36.6 4705 112 15:48:00 AlarmDelta StageAtTopPerf=10 9818.81 3580 3751 36.6 4731 113 15:52:12 StartFlush StartFlush 9972.1 3441 3586 35.2 4667 114 15:52:47 AlarmDelta StageAtTopPerf=11 9992.58 3533 3662 35 4665 115 15:56:18 AlarmDelta StageAtTopPerf=12 10116.43 3850 3958 37.8 4883 116 15:56:39 Other DropPump563ͲValvesAndSeats 10129 3784 3904 37.7 4876 117 16:00:42 ISIP ISIP 10266.89 737 207 0 3238 118 16:05:46 ShutͲInPressure@5Minutes ShutͲInPressure@5Minutes 10266.89 213 253 0 3153 119 16:10:38 ShutͲInPressure@10Minutes ShutͲInPressure@10Minutes 10266.89 17 32 0 3090 120 16:15:35 ShutͲInPressure@15Minutes ShutͲInPressure@15Minutes 10266.89 19 26 0 3041 EventLog12.11 ConocoPhillipsͲ3TͲ608 EventLog12.11 114 SeqNo. Time ActivityCode Comment JobSlurryVol TreatingPressureTreatingPressure@Pump SlurryRate TubingGaugeBHPres 1 06:00:22(12/15/24) Other CrewArrivedonLocation ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 2 6:31:32 PreͲJobSafetyMeetingPreͲJobSafetyMeeting ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 3 6:55:17 StartJob StartingJob 0 0 0 0 0 1 06:55:17(12/15/24) NextTreatment TreatmentInterval100000 4 6:58:17 Other WaitingonWater 0 5 Ͳ2 0 2267 5 8:08:46 PrimePumps PrimePumps 0 7 Ͳ2 0 2267 6 8:16:52 PressureTest ePRVͲPrimaryTubing 0 795 815 0 2267 7 8:18:13 PressureTest ePRVͲPrimaryIA 0 769 595 0 2267 8 8:19:19 PressureTest ePRVͲSecondaryTubing 0 770 793 0 2267 9 8:20:56 PressureTest ePRVͲSecondaryIA 0 822 792 0 2267 10 8:39:42 PressureTest PressureTestͲLocals 0 803 166 0 2267 11 8:40:14 PressureTest PressureTestͲGlobal 0 802 175 0 2267 12 8:47:09 PressureTest PressureTestͲMax 0 9475 9508 0 2267 13 8:52:09 PressureTest PressureTestͲPass 0 9252 9293 0 2267 11 10:16:51(12/15/24) NextTreatment TreatmentInterval11 0 73 50 0 2266 14 11:53:02 OpenWell OpenWell 2.17 538 430 0 2540 15 11:56:54 DropBall DropDartforInterval11 28.64 2426 2472 14.5 3998 16 12:13:25 BallonSeat DartonSeat 262.05 1832 1881 11.9 3726 17 12:13:40 BreakFormation BreakFormation 265.01 5206 5291 11.8 7262 18 12:13:55 Other StartDFIT 267.95 2412 2411 11.8 4177 19 12:14:36 AlarmDelta StageAtTopPerf=3 276.17 2667 2758 14.3 4455 20 12:14:44 AlarmDelta StageAtTopPerf=4 278.07 2989 3084 17.6 4706 21 12:16:15 AlarmDelta StageAtTopPerf=5 308.07 2707 2778 20 4308 22 12:17:33 ISIP ISIP 331.27 839 518 0 3096 23 12:22:34 ShutͲInPressure@5Minutes ShutͲInPressure@5Minutes 331.27 873 489 0 3039 24 12:27:34 ShutͲInPressure@10Minutes ShutͲInPressure@10Minutes 331.27 841 438 0 2997 25 12:32:28 ShutͲInPressure@15Minutes ShutͲInPressure@15Minutes 331.27 801 377 0 2959 26 12:45:53 Other PullingonChems 331.27 707 247 0 2867 27 13:04:53 StartPad StartPad 546.71 2788 2920 20.7 4397 28 13:05:51 AlarmDelta StageAtTopPerf=6 568.04 3335 3454 24.9 4825 29 13:07:11 AlarmDelta StageAtTopPerf=8 608.49 3927 4037 33.7 5024 30 13:12:58 AlarmDelta StageAtTopPerf=9 822.46 3738 3880 37.3 4813 31 13:17:56 AlarmDelta StageAtTopPerf=10 1007.78 3531 3653 37.3 4544 32 13:29:37 AlarmDelta StageAtTopPerf=11 1443.63 3048 3194 37.1 4260 33 13:30:55 AlarmDelta StageAtTopPerf=12 1491.87 3080 3238 37.1 4293 34 13:32:34 AlarmDelta StageAtTopPerf=13 1553.05 3144 3279 37 4309 35 13:35:24 AlarmDelta StageAtTopPerf=14 1657.95 3196 3350 37 4381 36 13:39:01 AlarmDelta StageAtTopPerf=15 1791.66 3243 3387 37 4415 37 13:42:48 AlarmDelta StageAtTopPerf=16 1931.29 3236 3404 36.9 4446 38 13:47:00 AlarmDelta StageAtTopPerf=17 2086.04 3258 3416 36.8 4479 39 13:51:19 AlarmDelta StageAtTopPerf=18 2244.97 3283 3453 36.8 4493 40 13:56:03 AlarmDelta StageAtTopPerf=19 2418.83 3469 3647 36.7 4623 41 13:58:25 DropBall DropDartforInterval12 2506.13 3879 3995 37.4 4667 12 13:58:28(12/15/24) NextTreatment TreatmentInterval12 2508.63 3928 4044 37.4 4682 42 13:59:07 AlarmDelta StageAtTopPerf=20 2532.91 3986 4093 37.4 4737 43 14:03:38 Other SlowDownForDart 2701.87 3133 3247 37.5 4217 44 14:05:33 BallonSeat DartonSeat 2728.31 2376 2475 12.3 3784 45 14:05:48 BreakFormation BreakFormation 2731.38 6121 6214 12.2 7445 46 14:06:12 AlarmDelta StageAtTopPerf=21 2736.46 3357 3401 12.2 4715 47 14:08:17 AlarmDelta StageAtTopPerf=1 2777.26 3800 3889 30.7 5056 48 14:13:22 AlarmDelta StageAtTopPerf=2 2963.78 3281 3393 37.1 4284 49 14:24:10 AlarmDelta StageAtTopPerf=3 3363.39 3279 3439 36.7 4286 50 14:25:29 AlarmDelta StageAtTopPerf=4 3411.68 3322 3492 36.6 4328 51 14:27:06 AlarmDelta StageAtTopPerf=5 3470.9 3397 3566 36.6 4403 52 14:30:01 AlarmDelta StageAtTopPerf=6 3577.73 3471 3634 36.6 4478 53 14:33:39 AlarmDelta StageAtTopPerf=7 3710.76 3488 3661 36.6 4514 54 14:37:31 AlarmDelta StageAtTopPerf=8 3852.24 3525 3696 36.6 4560 55 14:41:48 AlarmDelta StageAtTopPerf=9 4008.28 3502 3675 36.4 4553 56 14:46:10 AlarmDelta StageAtTopPerf=10 4167.31 3575 3745 36.4 4603 57 14:47:45 Other BinSwap 4224.35 3631 3801 36.5 4623 58 14:50:53 AlarmDelta StageAtTopPerf=11 4339.09 3599 3750 36.4 4669 59 14:52:30 StartFlush StartFlush 4398.67 3693 3830 37.1 4679 60 14:54:10 AlarmDelta StageAtTopPerf=12 4460.42 3869 3955 37 4685 61 15:00:01 ISIP ISIP 4672.34 1140 131 0 3331 62 15:05:02 ShutͲInPressure@5Minutes ShutͲInPressure@5Minutes 4672.34 315 346 0 3275 63 15:10:00 ShutͲInPressure@10Minutes ShutͲInPressure@10Minutes 4672.34 26 31 0 3244 64 15:14:58 ShutͲInPressure@15Minutes ShutͲInPressure@15Minutes 4672.34 25 26 0 3218 65 17:15:18 EndJob EndingJob 4672.34 19 12 0 2757 EventLog12.15 ConocoPhillipsͲ3TͲ608 EventLog12.15 115 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Test #1 Test #2 Test #3 Test #4 time (hr:min) -->00:00 01:00 02:00 03:00 04:00 05:00 10:00 15:00 20:00 25:00 30:00 45:00 1:00 1:15 1:30 1:45 2:00 2:15 2:30 2:45 3:00 3:30 4:00 4:30 5:00 5:30 6:00 6:30 Test #1 (cp) -->2345 1827 1852 1308 1407 1605 2049 1975 1926 1979 2006 1952 1738 1391 1284 1257 722 588 535 267 214 134 0 0 0 0 0 0 Dial Reading 95 74 75 53 57 65 83 80 72 74 75 73 65 52 48 47 27 22 20 10 8 5 Test #2 (cp) -->2407 1952 1444 1177 1016 1123 1257 1498 1391 1257 1284 1097 883 562 321 160 107 53 0000000000 Dial Reading 90 73 54 44 38 42 47 56 52 47 48 41 33 21 12 6 4 2 Test #3 (cp) -->0000000000000000000000000000 Dial Reading Test #4 (cp) -->0000000000000000000000000000 Dial Reading 3T-608 Stage(s): Break Test 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/7/2024 ConocoPhillips Project No: D. Martinez Hydration Visc: 25 98 Temperature was held at 140 degres for the duration of the test All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.00 Hydration pH: 7.39 Temp 0F PH LOSURF-300D WG-36 CAT3 MO-67 CL-28M BC-140X2 OptiFlo-II OptiFlo-III 98 8.88 1.00 30.00 0.00 0.24 1.00 98 8.88 1.00 30.00 0.00 0.24 1.00 0.25 3.00 0.25 2.00 2.00 2.00 0 500 1000 1500 2000 2500 3000 00:00 02:00 04:00 10:00 20:00 30:00 1:00 1:30 2:00 2:30 3:00 4:00 5:00 6:00Viscosity (cp)Time (min:sec) Prejob Crosslink Break Tests 30# Opti II @ 2.0 and Opti III @ 2.0 30 # Opti II @ 3.0 and Opti III @ 2.0 Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 PrejobBreakTest 116 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.25 ppg 1 ppg 2 ppg 3 ppg 4 ppg 0.25 2.00 2.0089 9.00 1.00 1.00 30.00 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.20 Hydration pH: 3T-608 Stage(s): 1 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/9/2024 Conoco Phillips Project No: 0 500 1000 1500 2000 2500 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 1 Crosslink Tests Pad 0.5 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone1 117 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.25 ppg 1 ppg 2 ppg 3 ppg 4 ppg 0.25 2.00 2.0089 9.00 1.00 1.00 30.00 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III D. Martinez Hydration Visc: 25 95 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.20 3T-608 Stage(s): 2 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/9/2024 Conoco Phillips Project No: 0 500 1000 1500 2000 2500 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 1 Crosslink Tests Pad 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone2 118 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 0.25 2.00 2.0089 9.00 1.00 1.00 30.00 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: 3T-608 Stage(s): 3 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/9/2024 Conoco Phillips Project No: 0 200 400 600 800 1000 1200 1400 1600 1800 2000 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 1 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone3 119 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 2.0089 9.00 1.00 1.00 30.00 0.25 2.00 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: 3T-608 Stage(s): 4 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/10/2024 Conoco Phillips Project No: 0 500 1000 1500 2000 2500 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 1 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone4 120 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 0.25 2.00 2.0091 9.00 1.00 1.00 30.00 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: 3T-608 Stage(s): 5 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/11/2024 Conoco Phillips Project No: 0 200 400 600 800 1000 1200 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 1 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone5 121 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 2.0089 9.00 1.00 1.00 30.00 0.25 2.00 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: 3T-608 Stage(s): 7 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/11/2024 Conoco Phillips Project No: 0 200 400 600 800 1000 1200 1400 1600 1800 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 1 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone7 122 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 2.0089 9.00 1.00 1.00 30.00 0.25 2.00 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: 3T-608 Stage(s): 8 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/11/2024 Conoco Phillips Project No: 0 500 1000 1500 2000 2500 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 1 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone8 123 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 2.0089 9.00 1.00 1.00 30.00 0.25 2.00 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: 3T-608 Stage(s): 9 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/11/2024 Conoco Phillips Project No: 0 500 1000 1500 2000 2500 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 1 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone9 124 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 2.0089 9.00 1.00 1.00 30.00 0.25 2.00 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: 3T-608 Stage(s): 10 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/11/2024 Conoco Phillips Project No: 0 200 400 600 800 1000 1200 1400 1600 1800 2000 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 1 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone10 125 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 2.0076 9.00 1.00 1.00 30.00 0.25 2.00 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: 3T-608 Stage(s): 11 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/11/2024 Conoco Phillips Project No: 8 0 200 400 600 800 1000 1200 1400 1600 1800 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 1 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone11 126 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 2.0079 9.00 1.00 1.00 30.00 0.25 2.00 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: 3T-608 Stage(s): 12 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 12/11/2024 Conoco Phillips Project No: 0 200 400 600 800 1000 1200 1400 1600 1800 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 1 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone12 127 Company: Well: SandType DateTested TotalSampleSize SeiveWeight SeiveWeight100.0 g SieveSize BeforeSand Withsand WT.rtn'd %rtn'd% APISpec 12 355.3 355.3 0 0.0% 0.00% <0.1% 16 340.3 344 3.7 3.7% 18 303.6 397.4 93.8 93.8% 20 296.5 298.8 2.3 2.3% 25 419.5 419.7 0.2 0.2% 30 281.7 281.7 0 0.0% 40 407.9 407.9 0 0.0% Pan 306.8 306.8 0 0.0% 0.00% <1.0% Total: 100 100% 96.30% >/=90% Sample: 16/20Ͳ12/08/2024 ConocoPhillips 3TͲ608 16/20Proppant 12/8/2024 CeramicProppantSieves ConocoPhillipsͲ3TͲ608 SandSieveAnalysis 128 Sales Order# Prepared By: William Martin Creighton Moore Nannook Crew 0909904452 Intervals 15-22 Moraine Notice:Althoughtheinformationcontainedinthisreportisbasedonsoundengineeringpractices,thecopyright owner(s)does(do)notacceptanyresponsibilitywhatsoever,innegligenceorotherwise,foranylossordamage arisingfromthepossessionoruseofthereportwhetherintermsofcorrectnessorotherwise.Theapplication, therefore,bytheuserofthisreportoranypartthereof,issolelyattheuser’sownrisk. 3T-608 Conoco Phillips Harrison Bay County, AK Post Job Report Stimulation Treatment API: 50-103-20889 Prepared for: Kirsty Glasheen March 3, 2025 Moraine Formation 30# Hybor G Hybrid Table of Contents Section Page(s) ExecutiveSummary ActualDesign WellboreInformation IntervalSummary FluidSystemͲProppantSummary Interval15Plots Interval16Plots Interval17Plots Interval18Plots Interval19Plots Interval20Plots Interval21Plots Interval22Plots Appendix WellSummary ChemicalSummary PlannedDesign WaterStraps3.1 WaterStraps3.2 WaterStraps3.3 WaterAnalysis2.24 WaterAnalysis3.1 WaterAnalysis3.2 RealͲTimeQC EventLog3.1 EventLog3.2 EventLog3.3 PrejobBreakTest Fann15minZone15 Zone16 Zone17 Zone18 Zone19 Zone20 Zone21 Zone22 SandSieveAnalysis 88 89 90 83 84 85 86 87 78 79 80 81 82 73 74 75 76 77 8Ͳ18 19 20Ͳ30 31Ͳ34 3 4Ͳ6 7 72 50Ͳ53 54Ͳ60 71 35Ͳ38 39Ͳ45 46Ͳ49 61Ͳ64 65 66 67 68Ͳ70 ConocoPhillipsͲ3TͲ608 TOC 2 58,451 gallons of 30# Linear 9,072 gallons of Freeze Protect 555,241 gallons of 30# Hybor G-i 1,553,000 pounds of Wanli 16/20 Ceramic 24,000 pounds of 100M 72,947 gallons of 30# Linear 12,180 gallons of Freeze Protect 586,356 gallons of 30# Hybor G-i 1,369,098 pounds of Wanli 16/20 Ceramic 24,000 pounds of 100M Thank you, William Martin Senior Technical Professional Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. EngineeringExecutiveSummary On March 01, 2025 a stimulation treatment was performed in the Moraine formation on the 3T-608 well in Harrison Bay County, AK. The 3T-608 was a 22 interval Horizontal Sleeve Design. The remaining 8 intervals of which were pumped on this second visit. The proposed treatment for the remaining 8 intervals consisted of: The actual treatment fully completed 7 of 8 intervals on the second visit. 0 intervals were skipped, 0 stage screened out and 1 stage was cut short of design. The actual treatment consisted of: A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided to summarize events and changes to the proposed treatment: The Treatment for 3T-608 was split into the toe completion and the heel completion. The toe completion, was hydraulically fractured in December of 2024. On March 1, 2025 Halliburton returned to hydraulically fracture intervals 15 through 22 (intervals 13 and 14 were skipped for formation reasons). Pad on interval 15 was extended because MO-67 froze on the ADP, MO-67 was swapped to an LA on the blender and the stage resumed. During the proppant laden fluid stages of interval 15, proppant concentration was fluctuating due to frozen proppant stuck in the gates of the Mover. While pumping interval 20, a water tank went empty and almost caused the blender to lose prime, proppant was cut and rate was dropped. Interval 20 was cut short by 50k lbs of proppant. Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids. No mid job design changes were made to the fluid system. Raw MO-67 was pumped from the blender. ConocoPhillipsͲ3TͲ608 ExecutiveSummary 3 CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDE BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) 50Ͳ103Ͳ20889 0909904452 LiquidAdditives DryAdditives 15Ͳ1 ShutͲIn ShutͲIn Ͳ 15Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,512 1,680 40 40 15Ͳ3 ShutͲIn ShutͲIn Ͳ 15Ͳ4 30#Linear Sweep 15.0 14,280 14,257 339 339 1.00 30.00 1.25 1.25 0.15 15Ͳ5 30#Linear SpacerandDartDrop 15.0 2,016 440 10 10 1.00 30.00 1.25 1.25 0.15 15Ͳ6 30#Linear Displacement 15.0 9,052 8,914 212 212 1.00 30.00 1.25 1.25 0.15 15Ͳ7 30#Linear DFIT 10.0 1,680 2,171 52 52 1.00 30.00 1.25 1.25 0.15 15Ͳ8 ShutͲIn ShutͲIn Ͳ 15Ͳ9 30#Linear StepRateTest 15.0 1,680 6,238 149 149 1.00 30.00 1.25 1.25 0.15 15Ͳ10 30#HyborGͲi EstablishStableFluid20.0 8,400 7,822 186 186 1.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ11 30#HyborGͲi Pad 37.0 11,810 21,128 503 503 1.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ12 30#Linear Flush 37.0 1 10,473 249 249 1.00 30.00 1.25 1.25 0.15 15Ͳ13 30#HyborGͲi Pad 37.0 1 11,928 284 284 1.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ14 30#HyborGͲi ConditioningPad 100M 0.25 37.0 12,000 12,308 293 295 3,000 2,174 1.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,899 45 46 2,000 1,048 1.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,616 62 67 5,000 4,747 1.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,952 94 106 12,000 11,030 1.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ18 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,833 115 134 19,400 18,021 1.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ19 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,876 116 138 22,500 20,717 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ20 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,352 127 155 27,050 25,569 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ21 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,485 131 162 30,250 29,637 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ22 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,741 137 173 34,800 34,625 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ23 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,212 100 127 26,000 25,126 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ24 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 5,194 124 154 21,000 28,619 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ25 30#HyborGͲiSpacerandDartDrop 37.0 2,016 2,293 55 55 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ1 30#HyborGͲi Pad 37.0 11,810 12,126 289 289 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37.0 12,000 12,079 288 290 3,000 1,933 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,905 45 47 2,000 1,240 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,783 66 72 5,000 5,271 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,957 94 107 12,000 11,792 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,876 116 137 19,400 19,350 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,949 118 141 22,500 22,220 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,355 128 155 27,050 26,258 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,411 129 160 30,250 29,271 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,722 136 172 34,800 33,991 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,997 95 122 26,000 25,260 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,997 119 149 21,000 28,569 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ13 30#HyborGͲiSpacerandDartDrop 37.0 2,016 2,713 65 65 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ1 30#HyborGͲi Pad 37.0 11,810 11,941 284 284 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37.0 12,000 12,093 288 292 3,000 3,298 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,894 45 47 2,000 1,632 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,546 61 66 5,000 5,048 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,989 95 108 12,000 11,860 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,834 115 136 19,400 19,365 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,932 117 141 22,500 22,199 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,366 128 156 27,050 26,286 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,502 131 163 30,250 30,018 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,788 138 174 34,800 33,813 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,988 95 121 26,000 24,631 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,681 111 137 21,000 24,213 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ13 30#Linear Flush 37.0 9,793 9,857 235 235 1.00 30.00 1.25 1.25 0.15 17Ͳ14 FreezeProtect FreezeProtect 10.0 1,512 3,780 90 90 17Ͳ15 ShutͲIn ShutͲIn ͲInterval 15Moraine@ 14161.08 - 14165.42 ft 139.6 °FInterval 17Moraine@ 13086.61 - 13090.95 ft 139.8 °FInterval 16Moraine@ 13624.66 - 13629 ft 139.9 °FConocoPhillipsͲ3TͲ608 ActualDesign 4 CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDE BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) 50Ͳ103Ͳ20889 0909904452 LiquidAdditives DryAdditives 18Ͳ1 ShutͲIn ShutͲIn Ͳ 18Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,512 2,016 48 48 18Ͳ3 ShutͲIn ShutͲIn Ͳ 18Ͳ4 30#Linear SpacerandDartDrop 15.0 1,260 1,567 37 37 1.00 30.00 1.25 1.25 0.15 18Ͳ5 30#HyborGͲi EstablishStableFluid20.0 8,400 6,997 167 167 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ6 30#HyborGͲi Pad 37.0 11,810 11,899 283 283 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ7 30#HyborGͲi ConditioningPad 100M 0.25 37.0 12,000 13,875 330 333 3,000 2,532 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,013 48 50 2,000 2,283 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,484 59 64 5,000 5,029 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,909 93 105 12,000 11,462 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,805 114 134 19,400 18,428 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,978 119 142 22,500 22,460 1.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,417 129 157 27,050 26,192 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 18Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,451 130 161 30,250 29,680 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 18Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,801 138 176 34,800 35,726 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 18Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,868 92 121 26,000 26,848 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 18Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,106 98 123 21,000 23,327 1.00 0.25 1.00 0.42 30.00 1.25 1.35 0.15 18Ͳ18 30#HyborGͲiSpacerandDartDrop 37.0 2,016 2,350 56 56 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ1 30#HyborGͲi Pad 37.0 11,810 11,934 284 284 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37.0 12,000 12,085 288 291 3,000 2,860 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 2,024 48 50 2,000 1,985 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,491 59 65 5,000 5,499 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,923 93 106 12,000 12,100 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,745 113 134 19,400 19,658 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,879 116 140 22,500 22,897 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,296 126 155 27,050 27,122 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,301 126 158 30,250 29,622 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,718 136 173 34,800 35,076 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,975 95 123 26,000 26,643 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 3,952 94 116 21,000 20,433 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ13 30#HyborGͲiSpacerandDartDrop 37.0 2,016 2,319 55 55 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ1 30#HyborGͲi Pad 37.0 11,810 11,826 282 282 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37.0 12,000 11,069 264 268 3,000 4,138 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,992 47 49 2,000 1,882 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 3,214 77 84 5,000 6,687 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,819 91 103 12,000 11,140 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,645 111 130 19,400 18,014 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,943 118 141 22,500 21,934 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,333 127 154 27,050 25,698 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,501 131 162 30,250 29,178 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 7,181 171 208 34,800 34,817 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ11 30#Linear Flush 37.0 9,299 9,299 221 221 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ12 FreezeProtect FreezeProtect 5.0 1,512 1,260 30 30 0.42 20Ͳ13 ShutͲIn ShutͲIn Ͳ 0.42Interval 18Moraine@ 12549.59 - 12553.93 ft 139.6 °FInterval 19Moraine@ 12013.48 - 12017.82 ft 139.4 °FInterval 20Moraine@ 11475.64 - 11479.98 ft 139.4 °FConocoPhillipsͲ3TͲ608 ActualDesign 5 CUSTOMER ConocoPhillipsAPI BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDE BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(psi)8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean ActualClean ActualClean CalculatedSlurry DesignProp CalculatedProp CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Volume Total Total Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (gal) (bbl) (bbl) (lbs) (lbs)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) 50Ͳ103Ͳ20889 0909904452 LiquidAdditives DryAdditives 21Ͳ1 ShutͲIn ShutͲIn Ͳ 21Ͳ2 FreezeProtect PrimeUpPressureTest 5.0 1,512 1,764 42 42 21Ͳ3 ShutͲIn ShutͲIn Ͳ 0.42 21Ͳ4 30#Linear SpacerandDartDrop 15.0 1,260 1,539 37 37 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ5 30#HyborGͲi EstablishStableFluid20.0 8,400 5,403 129 129 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ6 30#HyborGͲi Pad 37.0 11,810 11,897 283 283 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ7 30#HyborGͲi ConditioningPad 100M 0.25 37.0 12,000 11,925 284 287 3,000 2,923 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,927 46 48 2,000 1,534 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,521 60 65 5,000 5,075 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 3,986 95 108 12,000 11,896 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,834 115 136 19,400 19,276 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,990 119 143 22,500 22,682 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,354 127 156 27,050 26,967 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,515 131 164 30,250 30,573 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,798 138 175 34,800 34,758 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 3,996 95 123 26,000 26,467 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 3,970 95 116 21,000 20,402 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 21Ͳ18 30#HyborGͲiSpacerandDartDrop 37.0 2,016 2,153 51 51 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ1 30#HyborGͲi Pad 37.0 11,810 11,945 284 284 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37.0 12,000 12,590 300 303 3,000 2,603 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37.0 2,000 1,995 48 50 2,000 2,394 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37.0 2,500 2,483 59 64 5,000 4,942 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37.0 4,000 4,001 95 108 12,000 12,011 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37.0 4,850 4,827 115 135 19,400 19,188 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37.0 5,000 4,970 118 142 22,500 22,131 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37.0 5,410 5,390 128 156 27,050 26,383 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37.0 5,500 5,499 131 161 30,250 28,176 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37.0 5,800 5,719 136 172 34,800 33,457 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37.0 4,000 4,046 96 125 26,000 27,355 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37.0 3,000 4,441 106 131 21,000 23,989 1.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 22Ͳ13 30#Linear Flush 37.0 8,130 8,192 195 195 1.00 30.00 1.25 1.25 0.15 22Ͳ14 FreezeProtect FreezeProtect 10.0 1,512 1,680 40 40 22Ͳ15 ShutͲIn ShutͲIn Ͳ 650,524 671,483 15,988 17,661 1,577,000 1,575,363 DesignTotal(gal)ActualTotal(gal)DesignTotal(lbs)CalculatedTotal(lbs)TicketTotal(lbs)CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 1,553,000 1,552,902 1,369,098 (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs) 58,451 72,947 24,000 22,461 24,000 InitialDesignMaterialVolume 557.5 138.8 613.7 222.6 18,410.8 767.1 767.1 92.1 ͲͲ Ͳ ActualDesignMaterialVolume 588.7 146.6 659.3 237.8 19,779.1 824.1 824.5 98.9 9,072 12,180 Ͳ6720 ͲͲ Ͳ PhysicalMaterialVolumePumped 610 152 690 255 19879 850 850 130 555,241 586,356 ͲͲ Ͳ PhysicalMaterialVolumeDeviance 3.6% 3.7% 4.7% 7.2% 0.5% 3.1% 3.1% 31.5% ͲͲ **IFSnumbersforproppantaretakenfromsoftwarecalculationsbasedonmultiplevariables MicroMotionVolumePumped 612 147 652 219 22,013 830 853 Ͳ ͲͲ **ProppantisbilledfromWeightTicketvolumes MicroMotionVolumeDeviance 4% 0%Ͳ1%Ͳ8% 11% 1% 3%Ͳ ͲͲ Ͳ FluidType 30#HyborG 30#Linear Seawater FreezeProtect 30#HyborGͲi ProppantType Wanli16/20Ceramic 100M Ͳ ͲInterval 21Moraine@ 10979.99 - 10984.33 ft 139.4 °FInterval 22Moraine@ 10485.21 - 10489.55 ft 138.8 °FͲ Ͳ Ͳ ConocoPhillipsͲ3TͲ608 ActualDesign 6 ConocoPhillips Moraine 3TͲ608 50Ͳ103Ͳ20889 *Exceeds80%ofburstpressure* Description OD(in) ID(in) Wt(#) Grade FUF (gal/ft) MDTop (ft)MDBtm(ft) Volume(gal)TubularBurst Pressure(psi) Tubing 4.5 3.958 12.6 LͲ80 0.6392 0 8,148 5,208 8,430 Tubing 4.5 3.958 12.6 LͲ80 0.6392 8,148 22,000 8,854 8,430 Total 22,000 14,062 ft 1.55 ft 139.9 ft ft 1.55 ft 139.9 ft TopMD (ft)BtmMD(ft)Average TVD(ft)Interval# FormationDescriptor AverageInterval Temperature(F) BallDropTime (HH:MM) BallHitTime (HH:MM) JSVDrop (bbl) JSVSlow Down(bbl)JSVHit(bbl)Early(bbl)SurfaceSeat Pressure(psi) SurfacePeak Pressure(psi)SurfaceDifferential(psi)BHSeat Pressure(psi) BHPeak Pressure(psi) BH Differential (psi) RateatShift (bpm) Toe 20,989 20,993 5,063 1 Moraine 138.5 Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ ͲͲ Ͳ ͲͲͲͲ 20,562 20,566 5,067 2 Moraine 138.5 12:53:00PM 1:02:00PM 3,057 3,320 3,349 20.9 2,7336,3483,6154,1797,7053,52611.4 20,108 20,113 5,070 3 Moraine 138.6 3:17:00PM 3:27:00PM 5,997 6,253 6,297 6.0 3,0496,5063,4574,4017,6263,22512.5 19,654 19,659 5,074 4 Moraine 138.6 12:51:00PM 1:11:00PM 32 281 321 9.9 2,7576,2623,5053,9727,4463,47411.6 19,199 19,204 5,077 5 Moraine 138.7 10:26:00AM 10:45:00AM 41 283 320 13.2 2,3405,7373,3974,2647,4953,23112.2 18,661 18,665 5,084 6 Moraine 138.8 ͲͲͲͲͲͲ ͲͲ Ͳ ͲͲͲͲ 18,126 18,130 5,087 7 Moraine 138.8 12:14:00PM 12:23:00PM 2,445 2,671 2,713 7.9 2,9036,3213,4184,4157,8433,42811.9 17,672 17,676 5,079 8 Moraine 138.7 1:10:00PM 1:19:00PM 4,379 4,598 4,634 13.9 2,5356,1303,5953,9937,5723,57912.0 17,174 17,179 5,072 9 Moraine 138.6 2:05:00PM 2:13:00PM 6,248 6,459 6,496 13.4 2,5165,9593,4433,9517,1053,15411.9 16,681 16,685 5,070 10 Moraine 138.6 2:59:00PM 3:07:00PM 8,141 8,345 8,379 15.9 2,4295,9133,4843,8587,1493,29112.1 16,186 16,190 5,075 11 Moraine 138.7 11:56:00AM 12:13:PM 28 224 262 12.1 1,8325,4533,6213,7267,2613,53511.9 15,690 15,695 5,084 12 Moraine 138.8 1:58:00PM 2:05:00PM 2,507 2,696 2,728 17.8 2,3766,1373,7613,7847,4633,67912.3 15,195 15,199 5,101 13 Moraine 139.1 ͲͲͲͲͲͲ ͲͲ Ͳ ͲͲͲͲ 14,656 14,661 5,119 14 Moraine 139.3 ͲͲͲͲͲͲ ͲͲ Ͳ ͲͲͲͲ 14,161 14,165 5,136 15 Moraine 139.6 2:19:00PM 2:33:00PM 350 516 548 17.5 1,7925,0483,2563,6016,5402,93914.9 13,625 13,629 5,157 16 Moraine 139.9 6:02:00PM 6:06:00PM 3,607 3,764 3,799 15.4 2,0966,0723,9763,8137,4953,68215.2 13,087 13,091 5,151 17 Moraine 139.8 6:54:00PM 7:00:00PM 5,521 5,670 5,705 15.2 2,2085,2273,0193,6836,7203,03715.0 12,550 12,554 5,134 18 Moraine 139.6 1:42:00PM 1:52:00PM 29 170 208 12.0 1,7415,1053,3643,6396,7893,15015.0 12,013 12,018 5,125 19 Moraine 139.4 2:45:00PM 2:50:00PM 2,119 2,252 2,286 15.8 2,1335,5803,4473,6376,8733,23615.2 11,476 11,480 5,125 20 Moraine 139.4 3:36:00PM 3:41:00PM 3,978 4,103 4,137 15.6 1,9365,3403,4043,5086,6293,12115.0 10,980 10,984 5,122 21 Moraine 139.4 11:35:00AM 11:44:00AM 22 139 179 10.1 1,4224,4393,0173,2646,2522,98815.0 Heel 10,485 10,490 5,082 22 Moraine 138.8 12:34:00PM 12:40:00PM 2,031 2,141 2,183 7.6 1,9195,2293,3103,4496,3692,92015.1 207.4 199.2 191.0 182.8 174.6 275.9 268.9 261.4 253.9 246.3 238.8 167.1 159.6 8,365 8,022 7,679 7,335 7,018 6,702 10,029 9,712 9,368 9,052 8,709 11,586 11,296 10,978 10,662 10,346 12,853 306.0 12,563 12,272 11,928 DisplacementtoTop Sleeve/Perf(gal)(BBLS) 13,416 319.4 13,143 312.9 299.1 292.2 284.0 22 Interval# 1 MaxPressure(psi) 8,500 IsolationType CementedLiner TreatmentTubulars Customer Formation Lease API Date TemperatureData Temp.Gradient(°F/100ft) BHST(°F) DirectionalData 5,098 2,237 22,000 DirectionalData 2,237 3/1/2025 KOP TemperatureData Sleeve/PerfDepth Sleeves 231.2 223.1 215.5 7 8 9 10 11 2 3 4 5 6 17 18 19 20 21 12 13 14 15 16 Temp.Gradient(°F/100ft) BHST(°F)TVDatBottomPerf MDatBottomPerf 5,157 20,993 KOP Avg.TVD TotalMD ConocoPhillipsͲ3TͲ608 WellboreInformation 7 3/1/25 13:54 3/1/25 18:06 252 min 14.9 bpm 5,048 psi 6,540 psi 18 bbl 37.6 bpm 4,289 psi 5,573 psi 36.1 bpm 3,484 psi 3,289 psi 4,627 psi 3,085 hhp 450 psi 0 psi 721 psi 7.70 ppg 6 6 32 % 46 % 23 cP 90.2 F 8.5 DFIT 10.480 bpm 3131 psi 5091 psi 10.52 bpm 3320 psi 5278 psi 4783 psi 0.931 psi/ft 3685 psi 3493 psi 3374 psi 199,139 lbs 2,174 lbs 201,313 lbs 201,313 lbs Dart/Ball Early : Minifrac Average Rate: 3T-608 - Moraine - Interval 15 Interval Summary Diagnostic method Average Missile Pressure: Pad Percentage Actual Pumps Ending Stage: Pad Percentage Design End Date/Time: Max BH Pressure: Max Rate: Initial Surface Pressure (Breakdown): Open Well Pressure: Minifrac Max Rate: Initial Rate (Breakdown): Average Missile HHP: Initial BH Pressure (Breakdown): Average BH Pressure: Pump Time: Max Surface Pressure: Average Surface Pressure: Final 10 min: Average Visc: Average pH: Wanli 16/20 Ceramic Pumped: Proppant Summary Total Proppant Pumped* : Proppant in Formation: Final 15 min: Average Temp: Initial OA Pressure: Max OA Pressure: Max Proppant Concentration: 100M Pumped: Pumps Starting Stage: Final 5 min: Minifrac Average DH Pressure: Minifrac Average Pressure: Minifrac Max Surface Pressure: Final Fracture Gradient: Start Date/Time: ISDP: Minifrac Max DH Pressure: Average Rate: ConocoPhillipsͲ3TͲ608 IntervalSummary 8 42,493 gal 1,012 bbls 1,680 gal 40 bbls 99,639 gal 2,372 bbls 33,056 gal 787 bbls 12,308 gal 293 bbls 44,160 gal 1,051 bbls 8,914 gal 212 bbls 14,257 gal 339 bbls 2,733 gal 65 bbls 10,473 gal 249 bbls 6,238 gal 149 bbls 7,822 gal 186 bbls 2,171 gal 52 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: DFIT Volume: The day was started with a 340 bbl linear get sweep before dropping the dart for interval 15. After seating the dart a DFIT was pumped and pressure decline monitored for 1.5 hours. After resuming pumping, a step rate test was pumped before starting XL. After establishing XL, the LA for MO froze. A flush was called but the MO was reestablished on the blender before flushing the whole well. Pad was restarted and the stage was pumped to completion. There were issues with frozen proppant and debris causing rate and proppant concentration issues. 30# Hybor G-i Volume: Fluid Summary (by fluid description) Freeze Protect Volume: Interval Status: Creighton Moore Creighton Moore Pad Volume: Conditioning Pad Volume: Fluid Summary (by stage description) Flush Volume: Willie Martin Sweep Volume: Spacer and Dart Drop Volume: Proppant Laden Fluid Volume: Displacement Volume: 30# Linear Volume: Step Rate Test Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Establish Stable Fluid Volume: Chad Burkett ConocoPhillipsͲ3TͲ608 IntervalSummary 9 3/1/25 18:06 3/1/25 19:00 54 min 15.2 bpm 6,072 psi 7,495 psi 15 bbl 37.8 bpm 3,224 psi 4,214 psi 36.2 bpm 2,902 psi 2,676 psi 3,933 psi 2,578 hhp 684 psi 720 psi 7.37 ppg 6 6 32 % 31 % 22 cP 103 F 8.5 203,222 lbs 1,933 lbs 205,155 lbs 205,155 lbs 70,870 gal 1,687 bbls 12,126 gal 289 bbls 12,079 gal 288 bbls 43,952 gal 1,046 bbls 2,713 gal 65 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Willie Martin Creighton Moore Creighton Moore *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number.Chad Burkett Max Proppant Concentration: Pad Percentage Design Average Visc: Pump Time: Average Surface Pressure: Average Temp: Proppant in Formation: Average pH: Pumps Starting Stage: Start Date/Time: Average BH Pressure: Average Rate: End Date/Time: Max BH Pressure: Fluid Summary (by fluid description) Spacer and Dart Drop Volume: Interval Summary Pad Percentage Actual Initial OA Pressure: Initial BH Pressure (Breakdown): Dart/Ball Early : Average Missile HHP: Max OA Pressure: Conditioning Pad Volume: Proppant Laden Fluid Volume: Pumps Ending Stage: Max Surface Pressure: Pad Volume: Wanli 16/20 Ceramic Pumped: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): 100M Pumped: Average Missile Pressure: Proppant Summary Max Rate: 3T-608 - Moraine - Interval 16 Interval Status: Interval 16 was pumped to completion. 30# Hybor G-i Volume: Fluid Summary (by stage description) Total Proppant Pumped* : ConocoPhillipsͲ3TͲ608 IntervalSummary 10 3/1/25 19:00 3/1/25 19:51 51 min 15.0 bpm 5,227 psi 6,720 psi 15 bbl 37.9 bpm 3,564 psi 4,707 psi 36.8 bpm 3,038 psi 2,802 psi 4,113 psi 2,738 hhp 657 psi 707 psi 7.38 ppg 6 6 32 % 32 % 22 cP 108 F 8.7 3425 psi 0.665 psi/ft 3337 psi 3274 psi 3218 psi 199,065 lbs 3,298 lbs 202,363 lbs 202,363 lbs 3T-608 - Moraine - Interval 17 Interval Summary Average pH: ISDP: Final Fracture Gradient: Proppant Summary Average Rate: Final 5 min: Proppant in Formation: Average Missile Pressure: Initial Rate (Breakdown): Dart/Ball Early : Wanli 16/20 Ceramic Pumped: Final 10 min: 100M Pumped: Total Proppant Pumped* : End Date/Time: Max Proppant Concentration: Average BH Pressure: Start Date/Time: Pumps Ending Stage: Pad Percentage Design Pad Percentage Actual Final 15 min: Max Surface Pressure: Initial BH Pressure (Breakdown): Average Visc: Average Temp: Max OA Pressure: Average Surface Pressure: Max Rate: Initial OA Pressure: Max BH Pressure: Initial Surface Pressure (Breakdown): Pumps Starting Stage: Average Missile HHP: Pump Time: ConocoPhillipsͲ3TͲ608 IntervalSummary 11 9,857 gal 235 bbls 3,780 gal 90 bbls 67,554 gal 1,608 bbls 11,941 gal 284 bbls 12,093 gal 288 bbls 43,520 gal 1,036 bbls 9,857 gal 235 bbls 3,780 gal 90 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Pad Volume: Freeze Protect Volume: 30# Hybor G-i Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Freeze Protect Volume: 30# Linear Volume: Chad Burkett Flush Volume: Conditioning Pad Volume: Proppant Laden Fluid Volume: Fluid Summary (by fluid description) Fluid Summary (by stage description) Interval 17 was pumped to completion. During late sand stages there were minor proppant fluctuations due to frozen proppant chunks in the mover. Willie Martin Creighton Moore Creighton Moore Interval Status: ConocoPhillipsͲ3TͲ608 IntervalSummary 12 3/2/25 13:39 3/2/25 14:50 71 min 15.0 bpm 5,105 psi 6,789 psi 12 bbl 37.5 bpm 3,482 psi 4,224 psi 36.4 bpm 2,812 psi 2,682 psi 3,878 psi 2,508 hhp 428 psi 0 psi 570 psi 7.56 ppg 6 6 32 % 33 % 26 cP 91.1 F 8.6 201,435 lbs 2,532 lbs 203,967 lbs 203,967 lbs 1,567 gal 37 bbls 2,016 gal 48 bbls 77,953 gal 1,856 bbls 11,899 gal 283 bbls 13,875 gal 330 bbls 42,832 gal 1,020 bbls 3,917 gal 93 bbls 6,997 gal 167 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Willie Martin Proppant Summary Freeze Protect Volume: 30# Hybor G-i Volume: 100M Pumped: Creighton Moore Interval 18 was pumped to completion. Creighton Moore Chad Burkett Spacer and Dart Drop Volume: Interval Summary Average Temp: Average pH: Average BH Pressure: Pumps Starting Stage: Pumps Ending Stage: Start Date/Time: Average Surface Pressure: Dart/Ball Early : Initial BH Pressure (Breakdown): Pad Percentage Design Max Proppant Concentration: Pad Percentage Actual Average Missile Pressure: Max Rate: Average Missile HHP: Open Well Pressure: Max BH Pressure: Initial Surface Pressure (Breakdown): 3T-608 - Moraine - Interval 18 Pump Time: Interval Status: Initial Rate (Breakdown): Average Rate: Conditioning Pad Volume: End Date/Time: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Pad Volume: Initial OA Pressure: Max OA Pressure: Max Surface Pressure: Wanli 16/20 Ceramic Pumped: Establish Stable Fluid Volume: Proppant Laden Fluid Volume: Total Proppant Pumped* : Proppant in Formation: Average Visc: Fluid Summary (by stage description) 30# Linear Volume: Fluid Summary (by fluid description) ConocoPhillipsͲ3TͲ608 IntervalSummary 13 3/2/25 14:50 3/2/25 15:41 51 min 15.2 bpm 5,580 psi 6,873 psi 16 bbl 37.9 bpm 3,241 psi 4,000 psi 36.6 bpm 2,587 psi 2,455 psi 3,680 psi 2,318 hhp 627 psi 637 psi 7.44 ppg 6 6 32 % 32 % 23 cP 94 F 8.7 201,035 lbs 2,860 lbs 203,895 lbs 203,895 lbs 68,642 gal 1,634 bbls 11,934 gal 284 bbls 12,085 gal 288 bbls 42,304 gal 1,007 bbls 2,319 gal 55 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Interval Status: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number.Chad Burkett Average Temp: Average Missile Pressure: Average pH: Average BH Pressure: Total Proppant Pumped* : Proppant Laden Fluid Volume: Spacer and Dart Drop Volume: Fluid Summary (by stage description) Creighton Moore 30# Hybor G-i Volume: Fluid Summary (by fluid description) Pad Volume: Wanli 16/20 Ceramic Pumped: Interval Summary Average Visc: Start Date/Time: End Date/Time: Dart/Ball Early : Pumps Starting Stage: Max Rate: Initial Rate (Breakdown): Max BH Pressure: Average Rate: Pad Percentage Actual Max Surface Pressure: Pump Time: Initial OA Pressure: Initial BH Pressure (Breakdown): Max OA Pressure: Proppant in Formation: 100M Pumped: Conditioning Pad Volume: Average Missile HHP: Max Proppant Concentration: Pumps Ending Stage: 3T-608 - Moraine - Interval 19 Initial Surface Pressure (Breakdown): Average Surface Pressure: Pad Percentage Design Proppant Summary Interval 19 was pumped to completion Willie Martin Creighton Moore ConocoPhillipsͲ3TͲ608 IntervalSummary 14 3/2/25 15:41 3/2/25 16:30 49 min 15.0 bpm 5,340 psi 6,629 psi 16 bbl 37.7 bpm 2,970 psi 3,749 psi 34.6 bpm 2,408 psi 2,270 psi 3,523 psi 2,043 hhp 615 psi 645 psi 6.58 ppg 6 6 36 % 35 % 24 cP 96 F 8.6 149,350 lbs 4,138 lbs 153,488 lbs 153,488 lbs 9,299 gal 221 bbls 1,260 gal 30 bbls 59,523 gal 1,417 bbls 11,826 gal 282 bbls 11,069 gal 264 bbls 36,628 gal 872 bbls 9,299 gal 221 bbls 1,260 gal 30 bbls Cut Short Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Flush Volume: Total Proppant Pumped* : Proppant in Formation: 30# Linear Volume: Conditioning Pad Volume: Interval Summary Start Date/Time: End Date/Time: Pad Volume: Max BH Pressure: Average Rate: Average Missile Pressure: Average Surface Pressure: Average pH: Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Dart/Ball Early : Max Rate: Proppant Summary Wanli 16/20 Ceramic Pumped: 100M Pumped: Pumps Ending Stage: Average BH Pressure: Pump Time: Pad Percentage Design Average Temp: Fluid Summary (by fluid description) Fluid Summary (by stage description) Max OA Pressure: Pad Percentage Actual 30# Hybor G-i Volume: Average Missile HHP: Initial OA Pressure: 3T-608 - Moraine - Interval 20 Creighton Moore *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number.Chad Burkett Max Surface Pressure: Proppant Laden Fluid Volume: Max Proppant Concentration: Average Visc: Freeze Protect Volume: Interval Status: Willie Martin Creighton Moore Initial Rate (Breakdown): Pumps Starting Stage: Freeze Protect Volume: Interval 20 was cut short because the blenders were losing prime during 6.0 ppg. After losing prime, the screws were cut and rate was dropped. Flush was called after having to cut XL'ers and sand. ConocoPhillipsͲ3TͲ608 IntervalSummary 15 3/3/25 11:32 3/3/25 12:34 62 min 15.0 bpm 4,439 psi 6,252 psi 10 bbl 37.6 bpm 2,945 psi 3,863 psi 36.2 bpm 2,522 psi 2,329 psi 3,594 psi 2,235 hhp 492 psi 62 psi 498 psi 7.56 ppg 6 6 32 % 32 % 27 cP 87.1 F 8.6 199,630 lbs 2,923 lbs 202,553 lbs 202,553 lbs 1,539 gal 37 bbls 1,764 gal 42 bbls 74,269 gal 1,768 bbls 11,897 gal 283 bbls 11,925 gal 284 bbls 42,891 gal 1,021 bbls 3,692 gal 88 bbls 5,403 gal 129 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Interval Summary Proppant Summary Wanli 16/20 Ceramic Pumped: Fluid Summary (by fluid description) Fluid Summary (by stage description) Conditioning Pad Volume: Proppant Laden Fluid Volume: 30# Linear Volume: Freeze Protect Volume: Start Date/Time: End Date/Time: 30# Hybor G-i Volume: Pump Time: Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Dart/Ball Early : Max Rate: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Initial OA Pressure: Open Well Pressure: Max OA Pressure: Spacer and Dart Drop Volume: Proppant in Formation: Pad Volume: 100M Pumped: Average Missile HHP: Pumps Ending Stage: Average Visc: Max BH Pressure: Pad Percentage Design Average pH: Average BH Pressure: Pumps Starting Stage: Willie Martin Average Temp: Average Missile Pressure: Average Surface Pressure: Pad Percentage Actual Average Rate: Max Proppant Concentration: 3T-608 - Moraine - Interval 21 Creighton Moore Creighton Moore Chad Burkett Interval Status: Max Surface Pressure: Total Proppant Pumped* : Establish Stable Fluid Volume: Interval 21 was pumped to completion ConocoPhillipsͲ3TͲ608 IntervalSummary 16 3/3/25 12:34 3/3/25 13:34 60 min 15.1 bpm 5,229 psi 6,369 psi 8 bbl 38.3 bpm 4,752 psi 6,147 psi 34.8 bpm 3,356 psi 3,142 psi 4,453 psi 2,864 hhp 498 psi 595 psi 7.71 ppg 6 6 32 % 32 % 27 cP 82.2 F 8.7 3441 psi 0.677 psi/ft 3342 psi 3287 psi 3238 psi 200,026 lbs 2,603 lbs 202,629 lbs 202,603 lbs Final 10 min: Proppant in Formation: Total Proppant Pumped* : Interval Summary Dart/Ball Early : Average Missile Pressure: Initial OA Pressure: Average Surface Pressure: Max OA Pressure: Max Surface Pressure: Average Missile HHP: Average BH Pressure: Max BH Pressure: Max Rate: Start Date/Time: End Date/Time: Pump Time: Average Rate: Pad Percentage Actual Pumps Starting Stage: Pumps Ending Stage: Pad Percentage Design Average Visc: Average Temp: Initial BH Pressure (Breakdown): Average pH: Final 5 min: ISDP: Proppant Summary Wanli 16/20 Ceramic Pumped: Final Fracture Gradient: Max Proppant Concentration: Initial Surface Pressure (Breakdown): 3T-608 - Moraine - Interval 22 100M Pumped: Initial Rate (Breakdown): Final 15 min: ConocoPhillipsͲ3TͲ608 IntervalSummary 17 8,192 gal 195 bbls 1,680 gal 40 bbls 67,906 gal 1,617 bbls 11,945 gal 284 bbls 12,590 gal 300 bbls 43,371 gal 1,033 bbls 8,192 gal 195 bbls 1,680 gal 40 bbls Completed Comments: Engineer: Treater: Supervisor: Customer Engineer: Customer Rep: Proppant Laden Fluid Volume: Freeze Protect Volume: 30# Hybor G-i Volume: *Values for proppant are taken from software calculations based on multiple variables. Proppant is billed off of weight ticket volumes and may vary slightly from this number. Fluid Summary (by fluid description) Fluid Summary (by stage description) Pad Volume: Flush Volume: Freeze Protect Volume: After seating the ball, pressure was abnormally high so rate was slowly ramped to 37 bpm. After 100 Mesh hit downhole pressure broke over and treated at a lower pressure. Interval 22 was pumped to completion. Willie Martin Creighton Moore Creighton Moore 30# Linear Volume: Conditioning Pad Volume: Chad Burkett Interval Status: ConocoPhillipsͲ3TͲ608 IntervalSummary 18 Customer Formation Lease API Date WellSummary Wanli16/20Ceramic 100M TotalProppant BHPressure Rate Visc Temp pH BHPressure Rate gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs lbs 15 4627 36.1 23 90 8.5 5573 37.6 42,4931,0121,6804099,6392,372143,8123,424199,1392,174201,313 16 3933 36.2 22 103 8.5 4214 37.8 70,8701,68770,8701,687203,2221,933205,155 17 4113 36.8 22 108 8.7 4707 37.9 9,8572353,7809067,5541,60881,1911,933199,0653,298202,363 18 3878 36.4 26 91 8.6 4224 37.5 1,567372,0164877,9531,85681,5361,941201,4352,532203,967 19 3680 36.6 23 94 8.7 4000 37.9 68,6421,63468,6421,634201,0352,860203,895 20 3523 34.6 24 96 8.6 3749 37.7 9,2992211,2603059,5231,41770,0821,669149,3504,138153,488 21 3594 36.2 27 87 8.6 3863 37.6 1,539371,7644274,2691,76877,5721,847199,6302,923202,553 22 4453 34.8 27 82 8.7 6147 38.3 8,1921951,6804067,9061,61777,7781,852200,0262,603202,629 Minimum 1539371260305952314176864216341493501933153488 Average 121582892030487329517458393519981941132808196920 Maximum 42493101237809099639237214381234242032224138205155 Wanli16/20Ceramic 100M TotalProppant Pressure Rate Visc Temp pH Pressure Rate gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs Total Planned 58,451 1,392 0 0 9,072 216 555,241 13,220 622,764 14,828 1,553,000 24,000 1,577,000 Recorded 0 0.0 2 7 0.73 6147 38.3 72,947 1,737 0 0 12,180 290 586,356 13,961 671,483 15,988 1,552,902 22,461 1,575,363 WeightTickets 1,369,098 24,000 1,393,098 **ProppantisbilledfromWeightTicketvolumes **IFSnumbersforproppantaretakenfromsoftwarecalculationsbasedon TotalFluid Fluids Proppants Fluids Proppants 30#HyborGͲiTotalFluid FreezeProtect 30#HyborGͲi FreezeProtect Average Max Seawater30#Linear 30#LinearIntervalAverage Max Seawater March01,2025 50Ͳ103Ͳ20889 3TͲ608 Moraine ConocoPhillips ConocoPhillipsͲ3TͲ608 FluidSystemͲProppantSummary 19 <-Paste Interval 15 Plots Here ePRV Test - 3.1 3/1/2025 12:50 12:52 12:54 12:56 3/1/2025 12:58 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 2 1 22212019 Global Event Log 19 20 21 22 Intersection Intersection ePRV - Primary Tubing ePRV - Primary IA ePRV - Secondary Tubing ePRV - Secondary IA 12:49:44 12:52:08 12:55:35 12:57:39 TP TP 524.2 496.3 607.4 556.4 TPP TPP 574.3 494.4 634.9 612.6 IGKP IGKP 4500 4500 4500 4500 15 ConocoPhillipsͲ3TͲ608 Interval15Plots 20 <-Paste Interval 15 Plots HerePressure Test - 3.1 3/1/2025 13:05 13:10 3/1/2025 13:15 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 26252423 Global Event Log 23 24 25 26 Intersection Intersection Pressure Test - Locals Pressure Test - Global Pressure Test - Pass Pressure Test - Pass 13:01:36 13:02:35 13:10:53 13:15:51 TP TP 213.8 628.5 9504 9374 TPP TPP 245.6 642.6 9519 9380 IGKP IGKP 4500 500.0 9550 9550 PKP PKP 500.4 500.4 9451 9451 Customer: Conoco Phillips - Alaska Job Date: 01-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval15Plots 21 <-Paste Interval 15 Plots HereBlender Chemical Plot - Bucket Test 3.1 3/1/2025 07:10 07:20 07:30 07:40 3/1/2025 07:50 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal) A B A B A 1 ConocoPhillipsͲ3TͲ608 Interval15Plots 22 <-Paste Interval 15 Plots HereADP Chemical Plots - Bucket Test 3.1 3/1/2025 08:52 08:54 08:56 08:58 09:00 09:02 3/1/2025 09:04 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 7 ConocoPhillipsͲ3TͲ608 Interval15Plots 23 Treatment Plot - Interval 15 DFIT 3/1/2025 14:32 14:34 14:36 14:38 14:40 3/1/2025 14:42 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 87 ConocoPhillipsͲ3TͲ608 Interval15Plots 24 Pressure Testv2 - 3.1 3/1/2025 15:42 15:44 15:46 15:48 15:50 15:52 15:54 3/1/2025 15:56 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 4544 Global Event Log 44 45 Intersection Intersection Pressure Test - Start Pressure Test - Pass15:49:07 15:54:29 TP TP 9456 9230 TPP TPP 9532 9256 IGKP IGKP 9550 9550 PKP PKP 9451 9451 Customer: Conoco Phillips - Alaska Job Date: 01-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval15Plots 25 Treatment Plot - Interval 15 Step Rate Test 3/1/2025 16:05 16:10 16:15 3/1/2025 16:20 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 9 61605958575655545352515049484746 Global Event Log 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 Intersection Intersection Open Well SRT - Step 1 SRT - Step 2 SRT - Step 3 SRT - Step 4 SRT - Step 5 SRT - Step 6 SRT - Step 7 SRT- Step 8 SRT - Step 9 SRT - Step 10 SRT - Step 11 SRT - Step 12 SRT - Step 13 SRT - Step 14 SRT - Step 15 16:04:10 16:05:35 16:06:37 16:07:57 16:09:27 16:10:24 16:11:26 16:12:29 16:13:45 16:14:55 16:15:58 16:17:10 16:18:21 16:19:38 16:20:42 16:21:37 TP TP 753.8 1233 1899 2304 2474 2572 2755 2835 3026 3123 3233 3412 3607 3754 3848 3932 SR SR 0.000 0.918 1.893 2.786 3.724 4.654 5.571 6.569 7.597 8.495 9.406 10.33 11.31 12.32 13.31 14.20 GBP GBP 2955 3529 4131 4497 4624 4751 4943 5010 5193 5287 5389 5554 5680 5748 5809 5864 ConocoPhillipsͲ3TͲ608 Interval15Plots 26 Treatment Plot - Interval 15 3/1/2025 16:20 16:40 17:00 17:20 17:40 3/1/2025 18:00 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 2 1 25 24 23222120 19 18 17 16 1514131211109 16 ConocoPhillipsͲ3TͲ608 Interval15Plots 27 Blender Chemical Plot - Interval 15 3/1/2025 16:20 16:40 17:00 17:20 17:40 3/1/2025 18:00 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal)MO-67 BU (gal/Mgal) A B A B A A 2 1 2524232221201918 17 16 1514131211109 16 ConocoPhillipsͲ3TͲ608 Interval15Plots 28 ADP Chemical Plots - Interval 15 3/1/2025 16:20 16:40 17:00 17:20 17:40 3/1/2025 18:00 Time 0 10 20 30 40 50 A 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 BWG-36 Conc (lb/Mgal)MO-67 Conc (gal/Mgal)A B 2 1 2524232221201918 17 16 151413121110 16 ConocoPhillipsͲ3TͲ608 Interval15Plots 29 Net Pressure Plot - Interval 15 5 6 7 8 9 2 3 4 5 6 7 8 910 100 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3340 psi 0 Time = 03/01/25 16:00:26 1 Time -480.05 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 01-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval15Plots 30 <-Paste Interval 16 Plots HereTreatment Plot - Interval 16 3/1/2025 18:00 18:10 18:20 18:30 18:40 18:50 3/1/2025 19:00 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 1 1312111098765 4 3 2 1 1716 ConocoPhillipsͲ3TͲ608 Interval16Plots 31 <-Paste Interval 16 Plots HereBlender Chemical Plot - Interval 16 3/1/2025 18:00 18:10 18:20 18:30 18:40 18:50 3/1/2025 19:00 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal)MO-67 BU (gal/Mgal) A B A B A A 11312111098765 4 3 2 1 1716 ConocoPhillipsͲ3TͲ608 Interval16Plots 32 <-Paste Interval 16 Plots HereADP Chemical Plots - Interval 16 3/1/2025 18:00 18:10 18:20 18:30 18:40 18:50 3/1/2025 19:00 Time 0 10 20 30 40 50 WG-36 Conc (lb/Mgal) 11312111098765 4 3 2 1 1716 ConocoPhillipsͲ3TͲ608 Interval16Plots 33 <-Paste Interval 16 Plots HereNet Pressure Plot - Interval 16 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3340 psi 0 Time = 03/01/25 16:00:26 1 Time -480.05 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 01-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval16Plots 34 <-Paste Interval 17 Plots HereTreatment Plot - Interval 17 3/1/2025 19:00 19:10 19:20 19:30 19:40 3/1/2025 19:50 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 1312111098765 4 32117 ConocoPhillipsͲ3TͲ608 Interval17Plots 35 <-Paste Interval 17 Plots HereBlender Chemical Plot - Interval 17 3/1/2025 19:00 19:10 19:20 19:30 19:40 3/1/2025 19:50 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal)MO-67 BU (gal/Mgal) A B A B A A 1312111098765 4 32117 ConocoPhillipsͲ3TͲ608 Interval17Plots 36 <-Paste Interval 17 Plots HereADP Chemical Plots - Interval 17 3/1/2025 19:00 19:10 19:20 19:30 19:40 3/1/2025 19:50 Time 0 10 20 30 40 50 WG-36 Conc (lb/Mgal) 1312111098765 4 3211317 ConocoPhillipsͲ3TͲ608 Interval17Plots 37 <-Paste Interval 17 Plots HereNet Pressure Plot - Interval 17 2 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3340 psi 0 Time = 03/01/25 16:00:26 1 Time -480.05 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 01-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval17Plots 38 <-Paste Interval 18 Plots Here ePRV Test - 3.2 3/2/2025 11:55 12:00 12:05 12:10 12:15 3/2/2025 12:20 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 109876 Global Event Log 6 7 8 9 10 Intersection ePRV - Primary Tubing ePRV - Primary IA Trouble Shooting ePRV Relay on TCC ePRV - Secondary Tubing ePRV - Secondary IA 11:54:44 11:57:14 11:59:47 12:18:33 12:20:33 TP 708.2 916.0 347.2 599.2 418.0 TPP 715.0 894.5 373.6 651.7 467.7 IGKP 3500 3500 3500 3500 3500 ConocoPhillipsͲ3TͲ608 Interval18Plots 39 <-Paste Interval 18 Plots HerePressure Test - 3.2 3/2/2025 12:25 12:30 12:35 12:40 3/2/2025 12:45 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 16151413 12 11 Global Event Log 11 12 13 14 15 16 Intersection Intersection Pressure Test - Global Pressure Test - Locals Pressure Test - Start Tighten Wing Pressure Test - Start Pressure Test - Pass 12:25:11 12:25:27 12:29:02 12:36:48 12:41:15 12:46:17 TP TP 572.2 585.8 9520 40.70 9550 9360 TPP TPP 613.0 606.7 9556 28.34 9596 9372 IGKP IGKP 250.0 9550 9550 9550 9550 9550 PKP PKP 500.4 6012 9476 9476 9476 9476 Customer: Conoco Phillips - Alaska Job Date: 02-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval18Plots 40 <-Paste Interval 18 Plots HereBlender Chemical Plot - Bucket Test 3.2 3/2/2025 11:40 11:42 11:44 11:46 11:48 11:50 11:52 3/2/2025 11:54 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal)MO-67 Conc (gal/Mgal) A B A B A A ConocoPhillipsͲ3TͲ608 Interval18Plots 41 <-Paste Interval 18 Plots HereTreatment Plot - Interval 18 3/2/2025 13:40 14:00 14:20 3/2/2025 14:40 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 1 181716151413121110 9 876543 19 ConocoPhillipsͲ3TͲ608 Interval18Plots 42 Blender Chemical Plot - Interval 18 3/2/2025 13:40 13:50 14:00 14:10 14:20 14:30 14:40 3/2/2025 14:50 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal)MO-67 Conc (gal/Mgal) A B A B A A 1 181716151413121110 9 87654 19 ConocoPhillipsͲ3TͲ608 Interval18Plots 43 ADP Chemical Plots - Interval 18 3/2/2025 13:40 13:50 14:00 14:10 14:20 14:30 14:40 3/2/2025 14:50 Time 0 10 20 30 40 50 WG-36 Conc (lb/Mgal) 1 181716151413121110 9 87654 19 ConocoPhillipsͲ3TͲ608 Interval18Plots 44 Net Pressure Plot - Stage 18 3 4 5 6 7 8 9 100 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3380 psi 0 Time = 03/02/25 13:10:58 1 Time -205.03 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 02-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval18Plots 45 <-Paste Interval 19 Plots HereTreatment Plot - Interval 19 3/2/2025 14:50 15:00 15:10 15:20 15:30 3/2/2025 15:40 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 1 1312111098765 4 321 2019 ConocoPhillipsͲ3TͲ608 Interval19Plots 46 <-Paste Interval 19 Plots HereBlender Chemical Plot - Interval 19 3/2/2025 14:50 15:00 15:10 15:20 15:30 3/2/2025 15:40 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal)MO-67 Conc (gal/Mgal) A B A B A A 1 1312111098765 4 32 1 18 2019 ConocoPhillipsͲ3TͲ608 Interval19Plots 47 <-Paste Interval 19 Plots HereADP Chemical Plots - Interval 19 3/2/2025 14:50 15:00 15:10 15:20 15:30 3/2/2025 15:40 Time 0 10 20 30 40 50 WG-36 Conc (lb/Mgal) 1 1312111098765 4 32 1 18 2019 ConocoPhillipsͲ3TͲ608 Interval19Plots 48 <-Paste Interval 19 Plots HereNet Pressure Plot - Stage 19 100 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3380 psi 0 Time = 03/02/25 13:10:58 1 Time -205.03 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 02-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval19Plots 49 <-Paste Interval 20 Plots HereTreatment Plot - Interval 20 3/2/2025 15:40 15:50 16:00 16:10 16:20 3/2/2025 16:30 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 111098765 4 32120 ConocoPhillipsͲ3TͲ608 Interval20Plots 50 <-Paste Interval 20 Plots HereBlender Chemical Plot - Interval 20 3/2/2025 15:40 15:50 16:00 16:10 16:20 3/2/2025 16:30 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal)MO-67 Conc (gal/Mgal) A B A B A A 111098765 4 32120 ConocoPhillipsͲ3TͲ608 Interval20Plots 51 <-Paste Interval 20 Plots HereADP Chemical Plots - Interval 20 3/2/2025 15:40 15:50 16:00 16:10 16:20 3/2/2025 16:30 Time 0 10 20 30 40 50 WG-36 Conc (lb/Mgal) 111098765 4 3211320 ConocoPhillipsͲ3TͲ608 Interval20Plots 52 <-Paste Interval 20 Plots HereNet Pressure Plot - Stage 20 2 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3200 psi 0 Time = 03/02/25 13:10:58 1 Time -205.03 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 02-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval20Plots 53 <-Paste Interval 21 Plots Here ePRV Test - 3.3 3/3/2025 10:31 10:32 10:33 10:34 10:35 10:36 10:37 3/3/2025 10:38 Time 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 10987 Global Event Log 7 8 9 10 Intersection Intersection ePRV - Primary Tubing ePRV - Primary IA ePRV - Secondary Tubing ePRV - Secondary IA 10:31:32 10:33:16 10:35:21 10:37:00 TP TP 624.1 548.9 564.1 406.7 TPP TPP 674.4 507.7 632.0 467.5 IGKP IGKP 3500 3500 3500 3500 ConocoPhillipsͲ3TͲ608 Interval21Plots 54 <-Paste Interval 21 Plots HerePressure Test - 3.3 3/3/2025 10:40 10:45 10:50 10:55 11:00 3/3/2025 11:05 Time 0 2000 4000 6000 8000 10000 Treating Pressure (psi)Treating Pressure @Pump (psi)I1 Global Kickout Pressure (psi) P2 Kickout Pressure (psi)Pop-off (psi) 17161514 13 12 Global Event Log 12 13 14 15 16 17 Intersection Pressure Test - Global Pressure Test - Locals High Pressure Seal on LoTorq Pressure Test - Begin Pressure Test - Pass Bring on Chemicals 10:40:35 10:40:44 10:43:29 11:01:11 11:06:14 11:08:35 TP 548.4 554.6 5248 9480 9242 165.2 TPP 605.0 594.0 5234 9545 9276 149.4 IGKP 50.00 9550 9550 9550 9550 9550 PKP 500.4 500.4 9451 9451 9451 9451 Customer: Conoco Phillips - Alaska Job Date: 03-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval21Plots 55 <-Paste Interval 21 Plots HereBlender Chemical Plot - Bucket Test 3.3 3/3/2025 09:55 10:00 10:05 10:10 10:15 3/3/2025 10:20 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal)MO-67 Conc (gal/Mgal) A B A B A A ConocoPhillipsͲ3TͲ608 Interval21Plots 56 <-Paste Interval 21 Plots HereTreatment Plot - Interval 21 3/3/2025 11:40 11:50 12:00 12:10 12:20 12:30 3/3/2025 12:40 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 1 181716151413121110 9 8765 22 ConocoPhillipsͲ3TͲ608 Interval21Plots 57 Blender Chemical Plot - Interval 21 3/3/2025 11:40 11:50 12:00 12:10 12:20 12:30 3/3/2025 12:40 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal)MO-67 Conc (gal/Mgal) A B A B A A 1 181716151413121110 9 87654 22 ConocoPhillipsͲ3TͲ608 Interval21Plots 58 ADP Chemical Plots - Interval 21 3/3/2025 11:30 11:40 11:50 12:00 12:10 12:20 12:30 3/3/2025 12:40 Time 0 10 20 30 40 50 WG-36 Conc (lb/Mgal) 1 181716151413121110 9 87654 22 ConocoPhillipsͲ3TͲ608 Interval21Plots 59 Net Pressure Plot - Interval 21 3 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3200 psi 0 Time = 03/03/25 07:12:23 1 Time 50.95 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 03-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval21Plots 60 <-Paste Interval 22 Plots HereTreatment Plot - Interval 22 3/3/2025 12:40 12:50 13:00 13:10 13:20 3/3/2025 13:30 Time 0 1000 2000 3000 4000 5000 6000 7000 A 0 10 20 30 40 50 60 70 80 B 0 2 4 6 8 10 12 14 16 18 20 C 0 25 50 75 100 125 150 D Treating Pressure (psi)Slurry Rate (bpm) Slurry Proppant Conc (lb/gal)BH Proppant Conc (lb/gal) Gauge BH Pres (psi)Actual BH Temp (°F) A B C C A D 141312111098765 4 32122 ConocoPhillipsͲ3TͲ608 Interval22Plots 61 <-Paste Interval 22 Plots HereBlender Chemical Plot - Interval 22 3/3/2025 12:40 12:50 13:00 13:10 13:20 3/3/2025 13:30 Time 0.0 0.5 1.0 1.5 2.0 2.5 3.0 A 0 1 2 3 4 5 B Losurf-300D Conc (gal/Mgal)Optiflo-II Conc (lb/Mgal) BC-140 X2 Conc (gal/Mgal)Optiflo-III Conc (lb/Mgal) CL-28M Conc (gal/Mgal)MO-67 Conc (gal/Mgal) A B A B A A 141312111098765 4 32 1 1822 ConocoPhillipsͲ3TͲ608 Interval22Plots 62 <-Paste Interval 22 Plots HereADP Chemical Plots - Interval 22 3/3/2025 12:40 12:50 13:00 13:10 13:20 3/3/2025 13:30 Time 0 10 20 30 40 50 WG-36 Conc (lb/Mgal) 1312111098765 4 32 1 18 22 ConocoPhillipsͲ3TͲ608 Interval22Plots 63 <-Paste Interval 22 Plots HereNet Pressure Plot - Interval 22 Time (min) 2 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 100 1000 10000 Net Gauge BH Pres (psi) Slope of Net Pressure (psi/min) Closure Pressure = 3200 psi 0 Time = 03/03/25 07:12:23 1 Time 50.95 NetPr 0.000 Slope 0.000 Customer: Conoco Phillips - Alaska Job Date: 03-Mar-2025 Sales Order #: 0909904452 Well Description: 3T-608 3T-608 UWI: 50-103-20889 ConocoPhillipsͲ3TͲ608 Interval22Plots 64 Sales Order# Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ Ͳ EventLog SieveAnalysis Fann15Minute FieldBreakTest RealͲTimeQC WellSummary Stimulation Treatment Appendix ChemicalSummary PlannedDesign WaterStraps WaterAnalysis Prepared for: Kirsty Glasheen March 3, 2025 Harrison Bay County, AK 0909904452 Conoco Phillips 3T-608 Intervals 1-22 Moraine Moraine Formation API: 50-103-20889 ConocoPhillipsͲ3TͲ608 Appendix 65 Interval Date Designed Proppant (lbs) Proppantin Formation (lbs) DesignedFluid (bbl) VolClean (bbl) VolSlurry (bbl) PadPercentage Design PadPercentage Actual Proppant Aggressivness (lb/bblClean) FluidSystem Notes 15 3/1/2025 203,000201,313 2,536 3424 3,638 32.0 46.2 189 HyborͲHybrid PadExtendedͲLAissue 16 3/1/2025 203,000205,155 1,616 1687 1,905 32.0 31.4 194 HyborͲHybrid 17 3/1/2025 203,000202,363 1,837 1933 2,148 32.0 31.6 192 HyborͲHybrid 18 3/2/2025 203,000 203,967 1,882 1941 2158 32.0 33.3 198 HyborͲHybrid 19 3/2/2025 203,000 203,895 1,616 1634 1851 32.0 32.0 200 HyborͲHybrid 20 3/2/2025 156,000 153,488 1,659 1669 1832 36.4 34.8 171 HyborͲHybrid CutshortͲWaterPrime 21 3/3/2025 203,000 202,553 1,882 1847 2062 32.0 31.6 195 HyborͲHybrid 22 3/3/2025 203,000 202,603 1,798 1852 2067 32.0 32.0 194 HyborͲHybrid 3TͲ608IntervalHighlights ConocoPhillipsͲ3TͲ608 WellSummary 66 Customer ConocoPhillips Formation Moraine Lease 3TͲ608 API 50Ͳ103Ͳ20889 Date IntervalSummaryͲChemicals CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs) PrimeUp 00000000 15 106 27 138 34 4193 174 188 75 16 74 19 70 20 1994 88 88 0 17 50 19 87 31 2017 88 74 0 18 80 20 78 29 2717 97 101 55 19 80 18 69 29 2361 87 94 0 20 60 15 93 47 2122 116 105 0 21 77 19 75 30 2322 94 103 0 22 83 15 80 35 2153 106 97 0 Total 610 152 690 255 19879 850 850 130 w/oPrimeUp 610 152 690 255 19879 850 850 130 Interval 3/1/2025 DryAdditivesLiquidAdditives ConocoPhillipsͲ3TͲ608 ChemicalSummary 67 CUSTOMER ConocoPhillipsFALSE API BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDER BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(p8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean DesignClean DesignSlurry DesignProp Stage IntervalCLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time Time Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) 3/1/25 LiquidAdditives DryAdditives 50Ͳ103Ͳ20889 0909904452 15Ͳ1 ShutͲIn ShutͲIn 1:53:45 15Ͳ2 FreezeProtect PrimeUpPressureTest 5 1512 36360:07:121:53:45 15Ͳ3 ShutͲIn ShutͲIn 1:46:33 15Ͳ430#Linear Sweep 15 14280 3403400:22:401:46:331.00 30.00 1.25 1.25 0.15 15Ͳ530#Linear SpacerandDartDrop 15 2016 48480:03:121:23:531.00 30.00 1.25 1.25 0.15 15Ͳ630#Linear Displacement 15 9052 2162160:14:221:20:411.00 30.00 1.25 1.25 0.15 15Ͳ730#Linear DFIT 10 1680 40400:04:001:06:191.00 30.00 1.25 1.25 0.15 15Ͳ8 ShutͲIn ShutͲIn 1:02:19 15Ͳ930#Linear StepRateTest 15 1680 40400:02:401:02:191.00 30.00 1.25 1.25 0.15 15Ͳ10 30#HyborGͲi EstablishStableFluid20 8400 2002000:10:000:59:391.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ11 30#HyborGͲi Pad 37 11810 2812810:07:360:49:391.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ12 30#Linear Flush 37 1 000:00:000:42:031.00 30.00 1.25 1.25 0.15 15Ͳ13 30#HyborGͲiPad 371000:00:000:42:031.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ14 30#HyborGͲi ConditioningPad 100M 0.25 37 12000 2862893,000 0:07:490:42:031.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2000 48502,000 0:01:210:34:141.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2500 60655,000 0:01:450:32:531.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4000 9510812,000 0:02:560:31:081.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ18 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4850 11513619,400 0:03:410:28:121.00 0.25 1.00 0.35 30.00 1.25 1.25 0.15 15Ͳ19 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5000 11914322,500 0:03:530:24:311.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ20 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5410 12915827,050 0:04:170:20:381.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ21 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5500 13116330,250 0:04:260:16:221.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ22 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5800 13817534,800 0:04:450:11:561.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ23 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4000 9512326,000 0:03:200:07:111.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ24 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:03:511.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 15Ͳ25 30#HyborGͲiSpacerandDartDrop 37 2,016 48480:01:180:01:181.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ1 30#HyborGͲi Pad 37 11810 2812810:07:360:49:381.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37 12000 2862893,000 0:07:490:42:031.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2000 48502,000 0:01:210:34:141.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2500 60655,000 0:01:450:32:531.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4000 9510812,000 0:02:560:31:081.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4850 11513619,400 0:03:410:28:121.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5000 11914322,500 0:03:530:24:311.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5410 12915827,050 0:04:170:20:381.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5500 13116330,250 0:04:260:16:221.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5800 13817534,800 0:04:450:11:561.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4000 9512326,000 0:03:200:07:111.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3000 719421,000 0:02:330:03:511.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 16Ͳ13 30#HyborGͲiSpacerandDartDrop 37 2016 48480:01:180:01:181.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ1 30#HyborGͲi Pad 37 11810 2812810:07:360:58:151.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37 12000 2862893,000 0:07:490:50:391.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2000 48502,000 0:01:210:42:501.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2500 60655,000 0:01:450:41:291.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4000 9510812,000 0:02:560:39:441.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4850 11513619,400 0:03:410:36:491.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5000 11914322,500 0:03:530:33:071.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5410 12915827,050 0:04:170:29:141.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5500 13116330,250 0:04:260:24:581.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5800 13817534,800 0:04:450:20:321.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4000 9512326,000 0:03:200:15:471.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3000 719421,000 0:02:330:12:271.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 17Ͳ13 30#Linear Flush 37 9,793 2332330:06:180:09:541.00 30.00 1.25 1.25 0.15 17Ͳ14 FreezeProtect FreezeProtect 10 1,512 36360:03:360:03:36 17Ͳ15 ShutͲIn ShutͲInInterval 15Moraine@ 14161.08 - 14165.42 ft 139.6 °F"Frac Sleeve 14Interval 16Moraine@ 13624.66 - 13629 ft 139.9 °F"Frac Sleeve 15Interval 17Moraine@ 13086.61 - 13090.95 ft 139.8 °F"Frac Sleeve 16ConocoPhillipsͲ3TͲ608 PlannedDesign 68 CUSTOMER ConocoPhillipsFALSE API BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDER BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(p8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean DesignClean DesignSlurry DesignProp Stage IntervalCLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time Time Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) 3/1/25 LiquidAdditives DryAdditives 50Ͳ103Ͳ20889 0909904452 18Ͳ1 ShutͲIn ShutͲIn 1:08:50 18Ͳ2 FreezeProtect PrimeUpPressureTest 5 1,512 36360:07:121:08:50 18Ͳ3 ShutͲIn ShutͲIn 1:01:38 18Ͳ430#Linear SpacerandDartDrop 15 1,260 30300:02:001:01:381.00 30.00 1.25 1.25 0.15 18Ͳ5 30#HyborGͲi EstablishStableFluid20 8,400 2002000:10:000:59:381.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ6 30#HyborGͲi Pad 37 11,810 2812810:07:360:49:381.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ7 30#HyborGͲi ConditioningPad 100M 0.25 37 12,000 2862893,000 0:07:490:42:031.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2,000 48502,000 0:01:210:34:141.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2,500 60655,000 0:01:450:32:531.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4,000 9510812,000 0:02:560:31:081.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4,850 11513619,400 0:03:410:28:121.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5,000 11914322,500 0:03:530:24:311.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5,410 12915827,050 0:04:170:20:381.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5,500 13116330,250 0:04:260:16:221.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5,800 13817534,800 0:04:450:11:561.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4,000 9512326,000 0:03:200:07:111.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:03:511.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 18Ͳ18 30#HyborGͲiSpacerandDartDrop 37 2,016 48480:01:180:01:181.00 0.25 1.00 0.38 30.00 1.25 1.25 0.15 19Ͳ1 30#HyborGͲi Pad 37 11810 2812810:07:360:49:381.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37 12000 2862893,000 0:07:490:42:031.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2000 48502,000 0:01:210:34:141.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2500 60655,000 0:01:450:32:531.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4000 9510812,000 0:02:560:31:081.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4850 11513619,400 0:03:410:28:121.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5000 11914322,500 0:03:530:24:311.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5410 12915827,050 0:04:170:20:381.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5500 13116330,250 0:04:260:16:221.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5800 13817534,800 0:04:450:11:561.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4000 9512326,000 0:03:200:07:111.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3000 719421,000 0:02:330:03:511.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 19Ͳ13 30#HyborGͲiSpacerandDartDrop 37 2016 48480:01:180:01:181.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ1 30#HyborGͲi Pad 37 11810 2812810:07:360:55:391.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37 12000 2862893,000 0:07:490:48:031.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2000 48502,000 0:01:210:40:141.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2500 60655,000 0:01:450:38:531.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4000 9510812,000 0:02:560:37:081.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4850 11513619,400 0:03:410:34:121.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5000 11914322,500 0:03:530:30:311.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5410 12915827,050 0:04:170:26:381.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5500 13116330,250 0:04:260:22:221.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5800 13817534,800 0:04:450:17:561.00 0.25 1.00 0.42 30.00 1.25 1.25 0.15 20Ͳ11 30#Linear Flush 37 9299 2212210:05:590:13:111.00 0.42 30.00 1.25 1.25 0.15 20Ͳ12 FreezeProtect FreezeProtect 5 1512 36360:07:120:07:120.42 20Ͳ13 ShutͲIn ShutͲIn 0.42Interval 18Moraine@ 12549.59 - 12553.93 ft 139.6 °F"Frac Sleeve 17Interval 19Moraine@ 12013.48 - 12017.82 ft 139.4 °F"Frac Sleeve 18Interval 20Moraine@ 11475.64 - 11479.98 ft 139.4 °F"Frac Sleeve 18ConocoPhillipsͲ3TͲ608 PlannedDesign 69 CUSTOMER ConocoPhillipsFALSE API BFD(lb/gal)8.48 LAT70.42076262 LEASE 3TͲ608 SALESORDER BHST(°F)140 LONG Ͳ150.265422 FORMATION Moraine DATE MaxPressure(p8500 *Exceeds80%ofburstpressure* Prop Slurry DesignClean DesignClean DesignSlurry DesignProp Stage IntervalCLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Treatment Stage Fluid Stage Proppant Conc Rate Volume Volume Volume Total Time Time Crosslinker Crosslinker Surfactant Buffer Gel Breaker Breaker Biocide Interval Number Description Description Description (ppg) (bpm) (gal) (bbl) (bbl) (lbs) (hh:mm:ss) (hh:mm:ss)(gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (ppt) (ppt) 3/1/25 LiquidAdditives DryAdditives 50Ͳ103Ͳ20889 0909904452 21Ͳ1 ShutͲIn ShutͲIn 1:08:50 21Ͳ2 FreezeProtect PrimeUpPressureTest 5 1,512 36360:07:121:08:50 21Ͳ3 ShutͲIn ShutͲIn 1:01:380.40 21Ͳ430#Linear SpacerandDartDrop 15 1260 30300:02:001:01:381.00 0.40 30.00 1.25 1.25 0.15 21Ͳ5 30#HyborGͲi EstablishStableFluid20 8400 2002000:10:000:59:381.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ6 30#HyborGͲi Pad 37 11810 2812810:07:360:49:381.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ7 30#HyborGͲi ConditioningPad 100M 0.25 37 12000 2862893,000 0:07:490:42:031.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2000 48502,000 0:01:210:34:141.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2500 60655,000 0:01:450:32:531.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4000 9510812,000 0:02:560:31:081.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4850 11513619,400 0:03:410:28:121.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5000 11914322,500 0:03:530:24:311.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ13 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5410 12915827,050 0:04:170:20:381.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ14 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5500 13116330,250 0:04:260:16:221.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ15 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5,800 13817534,800 0:04:450:11:561.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ16 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4,000 9512326,000 0:03:200:07:111.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ17 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3,000 719421,000 0:02:330:03:511.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 21Ͳ18 30#HyborGͲiSpacerandDartDrop 37 2,016 48480:01:180:01:181.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ1 30#HyborGͲi Pad 37 11810 2812810:07:360:57:111.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ2 30#HyborGͲi ConditioningPad 100M 0.25 37 12000 2862893,000 0:07:490:49:351.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ3 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 1.00 37 2000 48502,000 0:01:210:41:461.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ4 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 2.00 37 2500 60655,000 0:01:450:40:251.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ5 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 3.00 37 4000 9510812,000 0:02:560:38:401.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ6 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.00 37 4850 11513619,400 0:03:410:35:441.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ7 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 4.50 37 5000 11914322,500 0:03:530:32:031.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ8 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.00 37 5410 12915827,050 0:04:170:28:101.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ9 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 5.50 37 5500 13116330,250 0:04:260:23:541.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ10 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.00 37 5800 13817534,800 0:04:450:19:281.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ11 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 6.50 37 4000 9512326,000 0:03:200:14:431.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ12 30#HyborGͲi ProppantLadenFluid Wanli16/20Ceramic 7.00 37 3000 719421,000 0:02:330:11:231.00 0.25 1.00 0.40 30.00 1.25 1.25 0.15 22Ͳ13 30#Linear Flush 37 8130 1941940:05:140:08:501.00 30.00 1.25 1.25 0.15 22Ͳ14 FreezeProtect FreezeProtect 10 1512 36360:03:360:03:36 22Ͳ15 ShutͲIn ShutͲIn 622,764 14,82816,5031,577,000 DesignTotal(gal)DesignTotal(lbs)CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 1,553,000 (gal) (gal) (gal) (gal) (lbs) (lbs) (lbs) (lbs) 58,451 24,000 InitialDesignMaterialVolume 557.5 138.8 613.7 222.6 18,410.8 767.1 767.1 92.1 Ͳ ChemicalExcess 836 180.5 797.8 289.4 23,934.0 997.2 997.2 119.7 9,072 Ͳ 555,241 Ͳ CLͲ28M BCͲ140X2 LosurfͲ300D MOͲ67 WGͲ36 OPTIFLOͲIII OPTIFLOͲII BEͲ6 Ͳ (gpm) (gpm) (gpm) (gpm) ppm ppm ppm ppm Ͳ MaxAdditiveRate 1.6 0.4 1.6 0.8 46.6 3.1 4.7 0.2 Ͳ MinAdditiveRate FluidType 30#HyborG 30#Linear Seawater FreezeProtect 30#HyborGͲi Ͳ Ͳ Ͳ ProppantType Wanli16/20Ceramic 100M Ͳ Ͳ ͲInterval 21Moraine@ 10979.99 - 10984.33 ft 139.4 °F"Frac Sleeve 20Interval 22Moraine@ 10485.21 - 10489.55 ft 138.8 °F"Frac Sleeve 218:41:47 ConocoPhillipsͲ3TͲ608 PlannedDesign 70 Customer: Well: Date: Formation: SO#: Tank Type WaterSource Inches Gallons Barrels Temperature(°F) Inches Gallons Barrels 1 Wichita CPF3 82 16,380 390 48 9,240 220 2 Wichita CPF3 83 16,590 395 48 9,240 220 3 Wichita CPF3 103 20,790 495 118 48 9,240 220 4 Wichita CPF3 103 20,790 495 120 48 9,240 220 5 Wichita CPF3 98 19,740 470 116 48 9,240 220 6 Wichita CPF3 98 19,740 470 12 2,268 54 7 Wichita CPF3 95 19,110 455 118 15 2,856 68 8 Wichita CPF3 90 18,060 430 123 15 2,856 68 9 Wichita CPF3 97 19,530 465 125 13 2,478 59 10 Wichita CPF3 98 19,740 470 127 15 2,856 68 11 Wichita CPF3 98 19,740 470 143 11 2,100 50 12 Wichita CPF3 104 21,000 500 141 104 21,000 500 13 Atigan CPF3 107 20,336 484 137 107 20,336 484 14 Atigan CPF3 100 18,981 452 140 100 18,981 452 15 Atigan CPF3 105 19,949 475 123 105 19,949 475 16 Atigan CPF3 103 19,562 466 125 68 12,792 305 17 Atigan CPF3 95 18,014 429 128 68 12,792 305 18 Atigan CPF3 104 19,755 470 124 68 12,792 305 19 Atigan CPF3 106 20,142 480 126 68 12,792 305 20 Atigan CPF3 107 20,336 484 129 68 12,792 305 21 Atigan CPF3 109 20,722 493 125 68 12,792 305 22 Atigan CPF3 100 18,981 452 123 69 12,985 309 23 Atigan CPF3 108 20,529 489 120 59 10,992 262 24 Atigan CPF3 118 6,720 160 121 59 10,992 262 TruckOffload 2,030 Gallons Barrels Gallons Barrels Gallons Barrels 455,237 12,869 253,603 6,038 201,634 6,831 Zones: 1 VolumeNeededforXIntervals(BBL): NumberofTanksNeeded:000 0 TankBottoms(BBL):515 515 515 515 ConocoPhillips 3TͲ608 3/1/2025 Moraine PreͲJobBarrelBottoms General BeginningStrap EndingStrap LocationSummary StartingVolume EndingVolume TotalUsed ConocoPhillipsͲ3TͲ608 WaterStraps3.1 71 Customer: Well: Date: Formation: SO#: Tank Type WaterSource Inches Gallons Barrels Temperature(°F) Inches Gallons Barrels 1 Wichita CPF3 8 1,512 36 8 1,512 36 2 Wichita CPF3 101 20,370 485 26 4,914 117 3 Wichita CPF3 105 21,000 500 118 15 2,856 68 4 Wichita CPF3 96 19,320 460 120 26 4,914 117 5 Wichita CPF3 101 20,370 485 116 10 1,890 45 6 Wichita CPF3 103 20,790 495 12 2,268 54 7 Wichita CPF3 11 2,100 50 118 16 3,024 72 8 Wichita CPF3 19 3,612 86 123 50 9,660 230 9 Wichita CPF3 15 2,856 68 125 49 9,450 225 10 Wichita CPF3 17 3,234 77 127 29 5,502 131 11 Wichita CPF3 16 3,024 72 143 58 11,340 270 12 Wichita CPF3 48 9,240 220 141 39 7,392 176 13 Atigan CPF3 103 19,562 466 137 71 13,372 318 14 Atigan CPF3 103 19,562 466 140 87 16,467 392 15 Atigan CPF3 102 19,368 461 123 87 16,467 392 16 Atigan CPF3 103 19,562 466 125 87 16,467 392 17 Atigan CPF3 102 19,368 461 128 87 16,467 392 18 Atigan CPF3 104 19,755 470 124 87 16,467 392 19 Atigan CPF3 102 19,368 461 126 87 16,467 392 20 Atigan CPF3 102 19,368 461 129 87 16,467 392 21 Atigan CPF3 102 19,368 461 125 38 6,737 160 22 Atigan CPF3 104 19,755 470 123 38 6,737 160 23 Atigan CPF3 105 19,949 475 120 19 3,452 82 24 Atigan CPF3 102 19,368 461 121 17 2,905 69 TruckOffload 1,450 Gallons Barrels Gallons Barrels Gallons Barrels 361,781 10,064 213,194 5,076 148,588 4,988 Zones: 1 VolumeNeededforXIntervals(BBL): NumberofTanksNeeded:000 0 TankBottoms(BBL):530 530 530 530 PreͲJobBarrelBottoms General BeginningStrap EndingStrap LocationSummary StartingVolume EndingVolume TotalUsed ConocoPhillips 3TͲ608 3/2/2025 Moraine ConocoPhillipsͲ3TͲ608 WaterStraps3.2 72 Customer: Well: Date: Formation: SO#: Tank Type WaterSource Inches Gallons Barrels Temperature(°F) Inches Gallons Barrels 1 Wichita CPF3 8 1,512 36 8 1,512 36 2 Wichita CPF3 26 4,914 117 26 4,914 117 3 Wichita CPF3 102 20,580 490 118 14 2,646 63 4 Wichita CPF3 103 20,790 495 120 18 3,402 81 5 Wichita CPF3 103 20,790 495 116 18 3,402 81 6 Wichita CPF3 100 20,160 480 14 2,646 63 7 Wichita CPF3 100 20,160 480 118 18 3,402 81 8 Wichita CPF3 103 20,790 495 123 38 7,224 172 9 Wichita CPF3 80 15,960 380 125 80 15,960 380 10 Wichita CPF3 29 5,502 131 127 29 5,502 131 11 Wichita CPF3 58 11,340 270 143 58 11,340 270 12 Wichita CPF3 39 7,392 176 141 39 7,392 176 13 Atigan CPF3 71 13,372 318 137 71 13,372 318 14 Atigan CPF3 87 16,467 392 140 87 16,467 392 15 Atigan CPF3 87 16,467 392 123 87 16,467 392 16 Atigan CPF3 87 16,467 392 125 87 16,467 392 17 Atigan CPF3 87 16,467 392 128 87 16,467 392 18 Atigan CPF3 87 16,467 392 124 87 16,467 392 19 Atigan CPF3 87 16,467 392 126 30 5,277 126 20 Atigan CPF3 87 16,467 392 129 30 5,277 126 21 Atigan CPF3 72 13,565 323 125 30 5,277 126 22 Atigan CPF3 72 13,565 323 123 14 2,357 56 23 Atigan CPF3 19 3,452 82 120 19 3,452 82 24 Atigan CPF3 17 2,905 69 121 17 2,905 69 TruckOffload Gallons Barrels Gallons Barrels Gallons Barrels 332,018 7,905 189,594 4,514 142,423 3,391 Zones: 1 VolumeNeededforXIntervals(BBL): NumberofTanksNeeded:000 0 TankBottoms(BBL):376 376 376 376 ConocoPhillips 3TͲ608 3/3/2025 Moraine PreͲJobBarrelBottoms General BeginningStrap EndingStrap LocationSummary StartingVolume EndingVolume TotalUsed ConocoPhillipsͲ3TͲ608 WaterStraps3.3 73 Specific Gravity Testing Temperature DissolvedIron (Fe2+) Chloride (ClͲ) Sulfate (SO4 2Ͳ) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH PostͲCrosslink pH Crosslink Bacteria Ͳ °F mg/L mg/L mg/L mg/L mg/L mg/L cP ͲͲ Ͳ (Y/N) BQValue Tank# H2S present? Y/N Hydrometer DigitalThermometer Strip Strip Strip Titration TotalHardness MinusCalcium Titration FANNͲ35 Probe Probe Probe Ͳ Mycometer 1 N 1.026 109.0 5 19,410 1,200 1,360 1,760 3,120 22.0 7.34 7.40 8.80 Y 22,099 2 N 1.026 98.0 5 21,120 1,200 1,280 2,040 3,320 21.0 7.20 7.40 8.70 Y 662 3 N 1.024 100.0 2 19,410 1,200 1,200 1,960 3,160 24.0 7.30 7.18 8.81 Y 25,259 4 N 1.026 100.0 2 23,030 1,200 1,280 2,080 3,360 22.0 7.30 7.43 8.86 Y 18,949 5 N 1.026 103.0 2 21,120 1,200 1,280 2,200 3,480 21.0 7.25 7.41 8.80 Y 897 6 N 1.028 105.0 2 23,030 1,200 1,120 2,600 3,720 23.0 7.20 7.41 8.70 Y 3,734 7 N 1.028 104.0 2 21,120 1,200 1,200 2,000 3,200 22.0 7.23 7.50 8.78 Y 23,678 8 N 1.026 108.0 2 21,120 1,200 1,080 2,400 3,480 22.0 7.48 7.50 8.80 Y 2,711 9 N 1.028 107.0 2 19,410 1,200 960 2,440 3,400 21.0 7.48 7.51 8.83 Y 3,221 10 N 1.028 108.0 2 25,170 1,200 1,120 2,200 3,320 22.0 7.25 7.42 8.90 Y 1,632 11 N 1.026 111.0 2 21,120 1,200 800 2,480 3,280 22.0 7.20 7.45 8.88 Y 1,457 12 N 1.026 109.0 2 21,120 1,200 840 2,640 3,480 23.0 7.23 7.42 8.81 Y 2,799 13 N 1.026 108.0 2 23,030 1,200 600 2,560 3,160 21.0 7.40 7.43 8.58 Y 7,848 14 N 1.026 112.0 2 23,030 1,200 800 2,760 3,560 21.0 7.43 7.41 8.78 Y 8,964 15 N 1.026 114.0 2 21,120 1,200 680 2,680 3,360 22.0 7.45 7.43 8.76 Y 4,396 16 N 1.026 115.0 5 21,120 1,200 920 2,400 3,320 21.0 7.40 7.41 8.81 Y 882 17 N 1.026 120.0 2 21,120 1,200 640 2,640 3,280 23.0 7.38 7.45 8.70 Y 549 18 N 1.026 123.0 2 21,120 1,200 680 2,760 3,440 21.0 7.23 7.30 8.81 Y 4,469 19 N 1.026 118.0 5 19,410 1,200 400 3,080 3,480 21.0 7.24 7.37 8.86 Y 5,338 20 N 1.026 115.0 2 21,060 1,200 1,080 2,080 3,160 22.0 7.28 7.41 8.80 Y 4,586 21 N 1.026 111.0 0 21,060 1,200 1,080 2,480 3,560 22.0 7.34 7.48 8.81 Y 3,265 22 N 1.026 109.0 0 21,060 1,200 960 2,720 3,680 21.0 7.39 7.45 8.85 Y 4,593 23 N 1.026 113.0 0 21,060 1,200 1,120 2,600 3,720 22.0 7.38 7.41 8.87 Y 4,436 24 N 1.026 119.0 0 22,800 1,200 920 2,280 3,200 23.0 7.40 7.46 8.83 Y 3,820 25 26 27 28 29 30 Average 1.026 2 21,382 1200 975 2410 3,385 21.9 7.32 7.42 8.80 Ͳ 6,677 Maximum 1.028 5 25,170 1,200 1,360 3,080 3,720 24.0 7.48 7.51 8.90 Ͳ 25,259 Minimum 1.024 0 19,410 1,200 400 2,000 3,160 21.00 7.20 7.30 8.58 Ͳ 549 Range 0.004 5 5,760 0 960 1,080 560 3.0 0.28 0.21 0.32 Ͳ 24,711 AlaskaDistrictFieldQC PrejobWaterAnalysisonLocation Company:ConocoPhillips WellName:3TͲ608 WaterSource:CPF3 ConocoPhillipsͲ3TͲ608 WaterAnalysis2.24 74 Specific Gravity Testing Temperature DissolvedIron (Fe2+) Chloride (ClͲ) Sulfate (SO4 2Ͳ) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH PostͲCrosslink pH Crosslink Bacteria Ͳ °F mg/L mg/L mg/L mg/L mg/L mg/L cP ͲͲ Ͳ (Y/N) BQValue Tank# H2S present? Y/N Hydrometer DigitalThermometer Strip Strip Strip Titration TotalHardness MinusCalcium Titration FANNͲ35 Probe Probe Probe Ͳ Mycometer 2 N 1.028 2 19,470 1,200 1,560 680 2,240 22,192 3 N 1.026 2 19,470 1,200 1,440 520 1,960 42,876 4 N 1.028 2 21,060 1,200 1,360 680 2,040 16,947 5 N 1.028 2 19,470 1,200 1,560 800 2,360 16,397 6 N 1.026 2 19,470 1,200 1,560 480 2,040 12,474 16 N 1.026 2 21,060 1,200 1,840 280 2,120 18,611 17 N 1.026 2 21,060 1,200 1,960 0 1,960 19,388 18 N 1.028 2 19,470 1,200 1,400 840 2,240 32,701 19 N 1.026 2 21,060 1,200 1,440 840 2,280 15,380 20 N 1.026 2 21,060 1,200 1,600 800 2,400 33,862 Average 1.027 2 20,265 1200 1,572 592 2,164 24.0 7.25 7.44 8.70 Ͳ 23,083 Maximum 1.028 2 21,060 1,200 1,960 840 2,400 24.0 7.26 7.45 8.70 Ͳ 42,876 Minimum 1.026 2 19,470 1,200 1,400 0 1,960 24.00 7.24 7.42 8.70 Ͳ 12,474 Range 0.002 0 1,590 0 560 840 440 0.0 0.02 0.03 0.00 Ͳ 30,402 AlaskaDistrictFieldQC PrejobWaterAnalysisonLocation Company:ConocoPhillips WellName:3TͲ608 WaterSource:CPF3 y 123.0 24.0 7.26 7.45 8.70 Y 119.0 24.0 7.24 7.42 8.70 ConocoPhillipsͲ3TͲ608 WaterAnalysis3.1 75 Specific Gravity Testing Temperature DissolvedIron (Fe2+) Chloride (ClͲ) Sulfate (SO4 2Ͳ) Calcium (Ca2+) Magnesium (Mg2+) Total Hardness Linear Viscosity Water pH Gel pH PostͲCrosslink pH Crosslink Bacteria Ͳ °F mg/L mg/L mg/L mg/L mg/L mg/L cP ͲͲ Ͳ (Y/N) BQValue Tank# H2S present? Y/N Hydrometer DigitalThermometer Strip Strip Strip Titration TotalHardness MinusCalcium Titration FANNͲ35 Probe Probe Probe Ͳ Mycometer 3 N 1.028 2 19,470 1,200 1,640 120 1,760 13,657 4 N 1.026 2 19,470 1,200 1,760 120 1,880 8,553 5 N 1.028 2 21,060 1,200 1,640 240 1,880 4,476 6 N 1.028 2 19,470 1,200 1,760 280 2,040 2,752 7 N 1.026 2 19,470 1,200 1,480 560 2,040 7,983 Average 1.027 2 19,788 1200 1,656 264 1,920 23.0 7.24 7.56 8.76 Ͳ 7,484 Maximum 1.028 2 21,060 1,200 1,760 560 2,040 23.0 7.24 7.56 8.76 Ͳ 13,657 Minimum 1.026 2 19,470 1,200 1,480 280 2,040 0.00 0.00 0.00 0.00 Ͳ 2,752 Range 0.002 0 1,590 0 280 280 0 23.0 7.24 7.56 8.76 Ͳ 10,905 AlaskaDistrictFieldQC PrejobWaterAnalysisonLocation Company:ConocoPhillips Y WellName:3TͲ608 WaterSource:CPF3 120.0 23.0 7.24 7.56 8.76 ConocoPhillipsͲ3TͲ608 WaterAnalysis3.2 76 Linear Linear XL XL XL Lip time Linear Linear XL XL XL Lip time Interval Stage Visc pH Temp °F pH min Interval Stage Visc pH Temp °F pH min 15 Pad 24 7.9 89 8.4 0 Pad .25# 23 7.3 90 8.4 0 23 Avg Linear Visc .25# #DIV/0! Avg Linear Visc 1.00# 90.2 Avg XLTemp 1.00# #DIV/0! Avg XLTemp 2.00# 22 7.1 92 8.4 0 8.4 Avg XL pH 2.00# #DIV/0! Avg XL pH 3.00#3.00# 4.00# 22 7.2 93 8.4 0 4.00# 4.50#4.50# 5.00# 23 7 93 8.4 0 5.00# 5.50#5.50# 6.00# 23 7.3 84 8.5 0 6.00# 6.50#6.50# 7.00#7.00# 16 Pad 0 Pad .25# 20 7.1 95 8.4 0 0.25# 1.00# 20 7.1 95 8.4 0 1.00# 2.00# 22 7 120 8.5 0 22 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 0 103.1 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 22 7.01 111 8.47 0 8.5 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50#4.50# 5.00# 23 7.1 108 8.52 0 5.00# 5.50#5.50# 6.00# 24 7 101 8.57 0 6.00# 6.50#6.50# 7.00# 22 7.02 92 8.74 0 7.00# 17 Pad Pad .25# 22 7.01 109 8.7 0 0.25# 1.00#1.00# 2.00# 22 7 84 8.7 0 22 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 98.7 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 22 7.03 100 8.69 0 8.7 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50#4.50# 5.00# 22 7.01 99 8.71 0 5.00# 5.50#5.50# 6.00# 22 7 102 8.77 0 6.00# 6.50#6.50# 7.00# 22 7 98 8.75 0 7.00# 18 Pad 31 7.01 90 8.65 0 Pad .25# 29 7.01 96 8.554 0 0.25# 1.00#1.00# 2.00# 26 7 90 8.6 0 26 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 91.1 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 25 7.02 92 8.6 0 8.6 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50#4.50# 5.00# 22 7.01 90 8.7 0 5.00# 5.50#5.50# 6.00# 22 7 90 8.6 0 6.00# 6.50#6.50# 7.00# 24 7.03 90 8.6 0 7.00# 19 Pad Pad .25# 22 7 100 8.6 0 0.25# 1.00#1.00# 2.00# 23 7 93 8.72 0 23 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 94.0 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 23 7.02 94 8.7 0 8.7 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50#4.50# 5.00# 24 7.01 90 8.7 0 5.00# 5.50#5.50# 6.00# 24 7 92 8.71 0 6.00# 6.50#6.50# 7.00# 23 7.03 95 8.68 0 7.00# 20 Pad Pad .25# 24 7 95 8.64 0 0.25# 1.00#1.00# 2.00# 23 7.02 94 8.7 0 23 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 95.4 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 24 7.01 95 8.5 0 8.6 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50#4.50# 5.00# 24 7.01 95 8.50 0 5.00# 5.50#5.50# 6.00# 22 7.01 98 8.7 0 6.00# 6.50#6.50# 7.00#7.00# 21 Pad 25 7.01 90 8.5 0 Pad .25# 26 7.02 92 8.5 0 0.25# 1.00#1.00# 2.00# 27 7.01 90 8.67 0 27 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 87.1 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 27 7.03 90 8.5 0 8.6 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50#4.50# 5.00# 27 7.01 90 8.6 0 5.00# 5.50#5.50# 6.00# 27 7.01 80 8.6 0 6.00# 6.50#6.50# 7.00# 28 7.01 78 8.7 0 7.00# 22 Pad 26 7 80 8.69 0 Pad .25# 27 7 85 8.71 0 0.25# 1.00#1.00# 2.00# 27 7 89 8.67 0 27 Avg Linear Visc 2.00# #DIV/0! Avg Linear Visc 3.00# 82.2 Avg XLTemp 3.00# #DIV/0! Avg XLTemp 4.00# 27 7.02 85 8.75 0 8.7 Avg XL pH 4.00# #DIV/0! Avg XL pH 4.50#4.50# 5.00# 26 7 79 8.6 0 5.00# 5.50#5.50# 6.00# 26 7.03 75 8.71 0 6.00# 6.50#6.50# 7.00# 27 7.01 78 8.77 0 7.00# Customer:HILCORP Wellname & #:3T-608 Date:March 1, 2025 Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments Comments ConocoPhillipsͲ3TͲ608 RealͲTimeQC77 SeqNo. Time ActivityCode Comment JobSlurryVol TreatingPressureTreatingPressure@Pump SlurryRate TubingGaugeBHPres 1 06:00:40(03/01/25) Other CrewArrivedonLocation ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 2 6:29:23 PreͲJobSafetyMeetingPreͲJobSafetyMeeting ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 3 7:00:06 Other PreͲJobPrep 0 ͲͲͲͲ ͲͲͲͲ 0 ͲͲͲͲ 4 7:09:26 StartJob StartingJob 0 0 0 0 0 1 07:09:26(03/01/25) NextTreatment TreatmentInterval10 0 0 0 0 5 7:10:13 Other BeginPressureTest 0.72 123 12 0.9 0 6 7:31:20 Other TroubleShootingFracShack 5.62 14 12 0 2127 7 8:54:07 Other ADPBucketTest 0 58 14 0 2127 8 9:08:10 PrimePumps PrimePumps 0 60 14 0 2127 9 9:14:29 Other LeakonWellSupportChiksantoAcidPumper0 69 156 0 2127 10 9:24:08 Other Tighten4"Chik 0 70 129 0 2127 11 9:29:22 Other RePrimeLines 0 71 25 0 2127 12 9:41:30 Other ReplaceSealon4"SinglebytheWell 0 89 122 0 2127 13 9:57:11 Other InvestigatePressureNotBleedingDown 0 66 127 0 2127 14 10:02:03 Other WalktheLines 0 68 402 0 2127 15 10:19:54 Other CannotGetFlowtoBleedOffTank 0 74 84 0 2127 16 12:00:25 PrimePumps PrimePumps 0 75 18 0 2127 17 12:01:15 Other CirculateWaterThroughAllGroundIron 0 74 21 0 2127 18 12:35:10 Other PrimeallPumps0 265 158 0 2127 15 12:48:44(03/01/25) NextTreatment TreatmentInterval15 0 123 99 0 2127 19 12:49:43 PressureTest ePRVͲPrimaryTubing 0 524 574 0 2127 20 12:52:07 PressureTest ePRVͲPrimaryIA 0 496 494 0 2127 21 12:55:35 PressureTest ePRVͲSecondaryTubing 0 607 635 0 2127 22 12:57:38 PressureTest ePRVͲSecondaryIA 0 556 613 0 2127 23 13:01:35 PressureTest PressureTestͲLocals 0 214 246 0 2127 24 13:02:35 PressureTest PressureTestͲGlobal 0 628 643 0 2127 25 13:10:53 PressureTest PressureTestͲPass 0 9504 9519 0 2127 26 13:15:50 PressureTest PressureTestͲPass 0 9374 9380 0 2127 27 13:17:55 Other LoadDarts 0 160 123 0 2127 28 13:19:33 Other LoadingChemsandMixingGel 0 138 36 0 2127 29 13:54:13 OpenWell OpenWell 0 450 454 0 2144 30 14:13:10 AlarmDelta StageAtTopPerf=1 250.88 1717 1795 15 3554 31 14:13:16 AlarmDelta StageAtTopPerf=4 252.38 1739 1823 15 3619 32 14:15:33 Other LoadDartForInterval15 286.57 1722 1797 14.9 3536 33 14:19:47 DropBall DropDartforInterval15 349.91 1755 1835 15 3573 34 14:33:03 BallonSeat Dart15onSeat 547.82 1792 1883 14.9 3601 35 14:33:14 BreakFormation BreakFormation 550.79 4836 4924 14.9 6518 36 14:36:57 AlarmDelta StageAtTopPerf=5 592.2 3191 3294 10.5 5160 37 14:37:57 AlarmDelta StageAtTopPerf=6 602.67 3272 3370 10.5 5228 38 14:39:04 ISIP ISIP 613.83 2489 2503 0.8 4783 39 14:44:19 ShutͲInPressure@5Minutes ShutͲInPressure@5Minutes 613.83 Ͳ20 37 0 3685 40 14:49:18 ShutͲInPressure@10Minutes ShutͲInPressure@10Minutes 613.83 Ͳ25 38 0 3493 41 14:54:21 ShutͲInPressure@15Minutes ShutͲInPressure@15Minutes 613.83 Ͳ28 38 0 3374 42 15:12:40 Other BlowingDownPumps613.83 Ͳ35 36 0 3123 43 15:30:02 PrimePumps PrimePumps 613.83 Ͳ6 37 0 2990 44 15:49:07 PressureTest PressureTestͲStart 613.83 9456 9532 0 2894 45 15:54:29 PressureTest PressureTestͲPass 613.83 9230 9256 0 2872 46 16:04:10 OpenWell OpenWell 613.83 754 759 0 2955 47 16:05:34 Other SRTͲStep1 614.74 1233 1340 0.9 3529 48 16:06:36 Other SRTͲStep2 616.51 1899 1989 1.9 4131 49 16:07:57 Other SRTͲStep3 620.19 2304 2381 2.8 4497 50 16:09:26 Other SRTͲStep4 625.64 2474 2524 3.7 4624 51 16:10:23 Other SRTͲStep5 629.93 2572 2642 4.7 4751 52 16:11:25 Other SRTͲStep6 635.46 2755 2841 5.6 4943 53 16:12:28 Other SRTͲStep7 641.84 2835 2914 6.6 5010 54 16:13:44 Other SRTͲStep8 650.99 3026 3106 7.6 5193 55 16:14:55 Other SRTͲStep9 660.44 3123 3203 8.5 5287 56 16:15:58 Other SRTͲStep10 669.96 3233 3324 9.4 5389 57 16:17:10 Other SRTͲStep11 681.94 3412 3515 10.3 5554 58 16:18:20 Other SRTͲStep12 695 3607 3702 11.3 5680 59 16:19:38 Other SRTͲStep13 710.41 3754 3840 12.3 5748 60 16:20:41 Other SRTͲStep14 724.24 3848 3942 13.3 5809 61 16:21:37 Other SRTͲStep15 736.95 3932 4040 14.2 5864 62 16:25:55 AlarmDelta StageAtTopPerf=7 814.97 4140 4201 20.3 5799 63 16:28:27 AlarmDelta StageAtTopPerf=9 866.57 3808 3875 20.4 5461 64 16:35:08 AlarmDelta StageAtTopPerf=10 1015.91 4154 4333 29.2 5553 65 16:37:52 Other LostLA4ADP 1099.16 4233 4391 31.1 5540 66 16:42:23 AlarmDelta StageAtTopPerf=11 1202.24 3949 4101 28.7 5442 67 16:43:54 Other ReestablishMO 1247.29 3641 3771 29.9 5206 68 16:46:56 Other LostMOͲ67Again 1349.91 4071 4247 35.5 5285 69 17:08:42 AlarmDelta StageAtTopPerf=12 1705.21 3036 3213 20.8 4784 70 17:15:33 AlarmDelta StageAtTopPerf=13 1954.17 3827 3995 37.6 5066 71 17:18:50 Other LostPump201ͲEngineIssue 2077.46 3742 3916 37.6 4994 72 17:23:16 AlarmDelta StageAtTopPerf=14 2237.91 3675 3834 37.6 4928 73 0.729953704 AlarmDelta StageAtTopPerf=15 2533.18 3323 3524 37.5 4722 74 17:32:22 AlarmDelta StageAtTopPerf=16 2579.4 3271 3468 37.5 4676 75 17:34:11 AlarmDelta StageAtTopPerf=17 2647.48 3193 3394 37.4 4558 76 17:35:25 Other DebrisThroughMultiplePumps 2693.65 3166 3380 37.4 4544 77 17:37:07 AlarmDelta StageAtTopPerf=18 2753.67 2831 3053 35.1 4354 78 17:40:33 Other 1ͲPreloadTransducerErrorKickeditOutͲPrel 2881.23 3078 3290 37.4 4438 79 17:40:46 AlarmDelta StageAtTopPerf=19 2888.57 2435 2644 30.6 4140 80 17:44:32 AlarmDelta StageAtTopPerf=20 3027.43 3029 3253 37.4 4384 81 17:48:42 AlarmDelta StageAtTopPerf=21 3183.09 3048 3277 37.3 4406 82 17:53:05 AlarmDelta StageAtTopPerf=22 3346.56 3138 3379 37.3 4453 83 17:53:28 Other FrozenSandinMountainMover 3360.84 3149 3388 37.2 4457 84 17:57:46 AlarmDelta StageAtTopPerf=23 3520.97 3193 3434 37.2 4532 85 17:58:46 Other DropRateduetoPrime 3557.56 2597 2743 35.2 4379 16 18:00:21(03/01/25) NextTreatment TreatmentInterval16 3607.32 3269 3448 36.6 4389 86 18:00:21 DropBall DropDartforInterval16 3607.93 3270 3449 36.6 4390 87 18:01:13 AlarmDelta StageAtTopPerf=24 3639.8 3320 3513 36.5 4472 88 18:06:02 BreakFormation BreakFormation 3790.7 2067 2240 15.2 3801 89 18:06:21 AlarmDelta StageAtTopPerf=25 3795.56 2087 2267 15.2 3810 90 18:06:34 BallonSeat DartonSeat 3798.6 2096 2279 15.2 3813 91 18:06:48 BreakFormation BreakFormation 3802.13 6054 6254 15.1 7472 92 18:09:03 AlarmDelta StageAtTopPerf=1 3850.41 2524 2693 37.5 3806 93 18:09:13 AlarmDelta StageAtTopPerf=2 3856.67 2523 2684 37.7 3761 94 18:24:31 AlarmDelta StageAtTopPerf=3 4428.66 2563 2771 37.2 3856 95 18:24:43 Other Pump201KickedͲMechanicDiagnosing 4435.48 2439 2632 37.2 3863 96 18:25:53 AlarmDelta StageAtTopPerf=4 4475.7 2580 2808 37 3906 97 18:27:49 AlarmDelta StageAtTopPerf=5 4547.5 2564 2806 37.1 3936 98 18:30:43 AlarmDelta StageAtTopPerf=6 4655.12 2608 2864 37.1 3910 99 18:34:26 AlarmDelta StageAtTopPerf=7 4792.51 2722 2977 37.1 3977 100 18:38:16 AlarmDelta StageAtTopPerf=8 4934.55 2761 3017 37 4011 101 18:42:30 AlarmDelta StageAtTopPerf=9 5091.23 2803 3061 36.9 4042 102 18:46:52 AlarmDelta StageAtTopPerf=10 5252.49 2850 3111 36.9 4077 103 18:51:35 AlarmDelta StageAtTopPerf=11 5426.16 2924 3196 36.9 4106 104 18:54:08 DropBall DropDart17 5521.15 3215 3431 37.4 4162 17 18:54:08(03/01/25) NextTreatment TreatmentInterval17 5521.15 3216 3430 37.4 4163 105 18:54:41 AlarmDelta StageAtTopPerf=12 5541.7 3216 3414 37.4 4172 106 18:59:13 AlarmDelta StageAtTopPerf=13 5691.64 2144 2353 14.8 3673 107 19:00:06 BallonSeat Dart17onSeat 5704.84 2208 2448 15 3683 108 19:00:15 BreakFormation BreakFormation 5707.1 4700 4871 15 6607 109 19:02:45 AlarmDelta StageAtTopPerf=1 5756.36 3535 3721 37.7 4577 110 19:10:19 AlarmDelta StageAtTopPerf=2 6040.45 2992 3178 37.5 4147 111 19:18:07 AlarmDelta StageAtTopPerf=3 6332.78 2638 2858 37.4 4027 112 19:19:22 AlarmDelta StageAtTopPerf=4 6379.49 2621 2845 37.4 4009 113 19:21:08 AlarmDelta StageAtTopPerf=5 6445.55 2603 2841 37.4 4014 114 19:24:02 AlarmDelta StageAtTopPerf=6 6553.86 2625 2861 37.4 4043 115 19:27:41 AlarmDelta StageAtTopPerf=7 6690.12 2642 2876 37.3 4055 116 19:31:30 AlarmDelta StageAtTopPerf=8 6832.47 2656 2894 37.3 4068 117 19:35:42 AlarmDelta StageAtTopPerf=9 6989.05 2692 2934 37.2 4094 118 19:39:43 Other FrozenProppantinMover 7137.96 2734 2982 37.2 4111 119 19:40:06 AlarmDelta StageAtTopPerf=10 7152.83 2742 2988 37.3 4115 120 19:44:49 AlarmDelta StageAtTopPerf=11 7328.06 2768 3017 37.3 4152 121 19:48:06 AlarmDelta StageAtTopPerf=12 7450.4 3109 3466 37.3 4230 122 19:51:55 ISIP ISIP 7587.67 1518 1754 0 3425 123 19:56:54 ShutͲInPressure@5Minutes ShutͲInPressure@5Minutes 7587.67 1180 1379 0 3337 124 20:01:57 ShutͲInPressure@10Minutes ShutͲInPressure@10Minutes 7587.67 1321 1486 0 3274 125 20:06:53 ShutͲInPressure@15Minutes ShutͲInPressure@15Minutes 7587.67 1986 2139 0 3218 EventLog3.1 ConocoPhillipsͲ3TͲ608 EventLog3.1 78 SeqNo. Time ActivityCode Comment JobSlurryVol TreatingPressureTreatingPressure@Pump SlurryRate TubingGaugeBHPres 1 07:39:46(03/02/25) Other CrewArrivedOnLocation ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 2 7:59:57 PreͲJobSafetyMeetingPreͲJobSafetyMeeting ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 3 8:36:49 Other IceIntheWellhead ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 4 8:54:58 StartJob StartingJob 0 0 0 0 0 1 08:54:58(03/02/25) NextTreatment TreatmentInterval10 0 0 0 0 18 08:55:59(03/02/25) NextTreatment TreatmentInterval18 0 71 45 0 0 5 11:35:47 PrimePumps PrimePumps 0 168 170 0 2341 6 11:40:16 Other BucketTestBlenderChems 0 265 236 0 2340 7 11:54:44 PressureTest ePRVͲPrimaryTubing 0 708 715 0 2339 8 11:57:13 PressureTest ePRVͲPrimaryIA 0 916 895 0 2339 9 11:59:47 Other TroubleShootingePRVRelayonTCC 0 347 374 0 2339 10 12:18:33 PressureTest ePRVͲSecondaryTubing 0 599 652 0 2337 11 12:20:32 PressureTest ePRVͲSecondaryIA 0 418 468 0 2337 12 12:25:10 PressureTest PressureTestͲGlobal 0 572 613 0 2337 13 12:25:27 PressureTest PressureTestͲLocals 0 586 607 0 2337 14 12:29:01 PressureTest PressureTestͲStart 0 9520 9556 0 2336 15 12:36:48 Other TightenWing 0 41 28 0 2336 16 12:41:14 PressureTest PressureTestͲStart 0 9550 9596 0 2335 17 12:46:17 PressureTest PressureTestͲPass 0 9360 9372 0 2335 18 12:51:12 Other BringonChemicals 0 372 323 0 2335 19 13:39:24 OpenWell OpenWell 0 428 405 0 2438 20 13:42:44 DropBall DropDartforInterval18 28.85 1987 2026 14.9 3597 21 13:49:48 Other SlowDownforDart 162.64 2243 2282 19.7 3870 22 13:52:40 BallonSeat DartonSeatforInterval18 207.66 1741 1828 15 3639 23 13:52:50 BreakFormation BreakFormation 210.15 4581 4598 15 6731 24 13:53:53 AlarmDelta StageAtTopPerf=4 226.13 1622 1701 15 3436 25 13:55:11 AlarmDelta StageAtTopPerf=5 263.8 2562 2658 36.8 3742 26 13:59:38 AlarmDelta StageAtTopPerf=6 430.33 2625 2734 37.5 3755 27 14:07:11 AlarmDelta StageAtTopPerf=7 713.25 2675 2781 37.5 3809 28 14:16:08 AlarmDelta StageAtTopPerf=8 1047.02 2508 2634 37.3 3826 29 14:17:28 AlarmDelta StageAtTopPerf=9 1097.32 2515 2645 37.2 3825 30 14:19:13 AlarmDelta StageAtTopPerf=10 1161.87 2506 2648 37.2 3841 31 14:22:03 AlarmDelta StageAtTopPerf=11 1267.32 2529 2664 37.2 3859 32 14:25:40 AlarmDelta StageAtTopPerf=12 1402.36 2572 2740 37.1 3879 33 14:29:33 AlarmDelta StageAtTopPerf=13 1545.84 2660 2814 37.1 3923 34 14:33:48 AlarmDelta StageAtTopPerf=14 1703.26 2737 2897 37 3960 35 14:38:12 AlarmDelta StageAtTopPerf=15 1865.82 2854 3018 36.9 4012 36 14:43:01 AlarmDelta StageAtTopPerf=16 2043.24 3121 3297 37 4109 19 14:45:02(03/02/25) NextTreatment TreatmentInterval19 2118.35 3448 3571 37.3 4139 37 14:45:03 DropBall DropDartforInterval19 2118.98 3449 3571 37.3 4141 38 14:46:05 AlarmDelta StageAtTopPerf=17 2157.5 3441 3513 37.3 4201 39 14:50:14 AlarmDelta StageAtTopPerf=18 2280.84 2119 2221 15.1 3636 40 14:50:32 BallonSeat DartonSeatforInterval19 2285.39 2133 2234 15.2 3637 41 14:50:42 BreakFormation BreakFormation 2287.91 5344 5412 15.1 6873 42 14:52:46 AlarmDelta StageAtTopPerf=1 2337.29 2455 2556 37.4 3573 43 15:00:17 AlarmDelta StageAtTopPerf=2 2621.17 2268 2373 37.8 3541 44 15:08:00 AlarmDelta StageAtTopPerf=3 2912.39 2250 2394 37.7 3580 45 15:09:20 AlarmDelta StageAtTopPerf=4 2962.52 2290 2436 37.6 3608 46 15:11:04 AlarmDelta StageAtTopPerf=5 3027.64 2298 2454 37.6 3638 47 15:13:55 AlarmDelta StageAtTopPerf=6 3134.68 2346 2500 37.5 3675 48 15:17:31 AlarmDelta StageAtTopPerf=7 3269.57 2398 2552 37.4 3701 49 15:21:17 AlarmDelta StageAtTopPerf=8 3410.5 2452 2605 37.4 3735 50 15:25:28 AlarmDelta StageAtTopPerf=9 3566.87 2527 2680 37.3 3772 51 15:29:44 AlarmDelta StageAtTopPerf=10 3725.95 2610 2776 37.2 3781 52 15:34:26 AlarmDelta StageAtTopPerf=11 3900.61 2818 2984 37.4 3879 53 15:36:29 DropBall DropDartforInterval20 3977.69 3218 3333 37.6 3890 20 15:36:29(03/02/25) NextTreatment TreatmentInterval20 3977.69 3218 3333 37.6 3890 54 15:37:31 AlarmDelta StageAtTopPerf=12 4016.58 3169 3245 37.7 3942 55 15:41:30 AlarmDelta StageAtTopPerf=13 4133.34 1925 2021 15.1 3501 56 15:41:46 BallonSeat DartonSeatforInterval20 4137.38 1936 2030 15.1 3508 57 15:41:56 BreakFormation BreakFormation 4139.9 5224 5348 15.1 6467 58 15:44:10 AlarmDelta StageAtTopPerf=1 4188.99 2300 2397 37.3 3491 59 15:51:38 AlarmDelta StageAtTopPerf=2 4470.04 2231 2342 37.6 3455 60 15:58:47 AlarmDelta StageAtTopPerf=3 4738.69 2176 2316 37.5 3465 61 16:00:06 AlarmDelta StageAtTopPerf=4 4788.07 2208 2350 37.5 3488 62 16:02:20 AlarmDelta StageAtTopPerf=5 4871.71 2253 2416 37.4 3521 63 16:05:07 AlarmDelta StageAtTopPerf=6 4975.11 2363 2542 37.3 3556 64 16:08:36 AlarmDelta StageAtTopPerf=7 5105.58 2351 2470 37.3 3595 65 16:12:26 AlarmDelta StageAtTopPerf=8 5247.84 2366 2546 37.2 3619 66 16:16:36 AlarmDelta StageAtTopPerf=9 5402.75 2492 2673 37.1 3612 67 16:19:40 Other LostPrimeͲCutSand 5516.26 2538 2728 36.8 3633 68 16:20:57 Other OSRDecidedtoCallFlush 5551.4 1630 1751 10.7 3468 69 16:22:13 AlarmDelta StageAtTopPerf=10 5565.44 2089 2198 11.8 3535 70 16:24:39 Other Other 5605.01 2964 3156 36.5 3692 71 0.687037037 Other ndedFlushafterseeingPropSlugonInlineDe 5753.96 2004 2118 28.4 3444 72 16:30:05 AlarmDelta StageAtTopPerf=11 5775.31 1990 2105 28.5 3379 73 16:30:35 ISIP ISIP 5786.14 1225 1334 0 3222 74 16:35:08 ShutͲInPressure@5Minutes ShutͲInPressure@5Minutes 5786.14 Ͳ11 6 0 3155 75 16:40:04 ShutͲInPressure@10Minutes ShutͲInPressure@10Minutes 5786.14 Ͳ3 13 0 3117 76 16:45:04 ShutͲInPressure@15Minutes ShutͲInPressure@15Minutes 5786.14 Ͳ3 13 0 3095 EventLog3.2 ConocoPhillipsͲ3TͲ608 EventLog3.2 79 SeqNo. Time ActivityCode Comment JobSlurryVol TreatingPressureTreatingPressure@Pump SlurryRate TubingGaugeBHPres 1 05:40:27(03/03/25) Other CrewArrivedonLocation 0 ͲͲͲͲ ͲͲͲͲ 0 ͲͲͲͲ 2 6:29:54 PreͲJobSafetyMeetingPreͲJobSafetyMeeting ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 3 6:40:22 Other lenderWon'tStartͲHydraulicMotoronStarte ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ ͲͲͲͲ 4 7:12:23 StartJob StartingJob 0 0 0 0 0 1 07:12:23(03/03/25) NextTreatment TreatmentInterval10 0 0 0 0 21 07:12:44(03/03/25) NextTreatment TreatmentInterval21 0 78 14 0 0 5 9:55:15 Other BucketTestBlender 0 49 Ͳ13 0 2352 6 10:08:29 Other PullonBrine 0 5 6 0 2351 7 10:10:54 PrimePumps PrimePumps 0 9 17 0 2351 8 10:31:31 PressureTest ePRVͲPrimaryTubing 0 624 674 0 2349 9 10:33:15 PressureTest ePRVͲPrimaryIA 0 549 508 0 2349 10 10:35:21 PressureTest ePRVͲSecondaryTubing 0 564 632 0 2349 11 10:37:20 PressureTest ePRVͲSecondaryIA 0 541 588 0 2349 12 10:40:35 PressureTest PressureTestͲGlobal 0 548 605 0 2348 13 10:40:44 PressureTest PressureTestͲLocals 0 555 594 0 2348 14 10:43:28 Other HighPressureSealonLoTorq 0 5248 5234 0 2348 15 11:01:11 PressureTest PressureTestͲBegin 0 9480 9545 0 2347 16 11:06:13 PressureTest PressureTestͲPass 0 9242 9276 0 2347 17 11:08:34 Other BringonChemicals 0 165 149 0 2346 18 11:32:39 OpenWell OpenWell 0 392 388 0 2388 19 11:35:42 DropBall DropDartforInterval21 21.94 1693 1781 14.9 3332 20 11:42:09 StartPad StartPad 147.28 1588 1670 16.1 3338 21 11:44:09 BallonSeat DartonSeatforInterval21 178.34 1422 1540 15.3 3264 22 11:44:19 BreakFormation BreakFormation 180.9 4348 4441 15.3 6249 23 11:45:42 AlarmDelta StageAtTopPerf=4 203.44 2308 2489 26.8 3779 24 11:46:43 AlarmDelta StageAtTopPerf=5 240.05 2473 2631 37.4 3714 25 11:50:08 AlarmDelta StageAtTopPerf=6 368.99 2440 2596 37.6 3622 26 11:57:41 AlarmDelta StageAtTopPerf=7 652.02 2358 2515 37.6 3577 27 12:05:20 AlarmDelta StageAtTopPerf=8 939.1 2187 2380 37.5 3542 28 12:06:37 AlarmDelta StageAtTopPerf=9 987.12 2229 2434 37.4 3557 29 12:08:22 AlarmDelta StageAtTopPerf=10 1052.46 2231 2434 37.3 3578 30 12:11:16 AlarmDelta StageAtTopPerf=11 1160.78 2246 2442 37.3 3589 31 12:14:55 AlarmDelta StageAtTopPerf=12 1297.04 2198 2402 37.3 3589 32 12:18:46 AlarmDelta StageAtTopPerf=13 1440.48 2220 2435 37.2 3578 33 12:23:00 AlarmDelta StageAtTopPerf=14 1597.94 2264 2494 37.1 3594 34 12:27:27 AlarmDelta StageAtTopPerf=15 1762.83 2398 2640 37 3624 35 12:32:14 AlarmDelta StageAtTopPerf=16 1939.17 2516 2766 36.8 3657 22 12:34:38(03/03/25) NextTreatment TreatmentInterval22 2028.28 2900 3100 37.5 3679 36 12:34:41 DropBall DropDartforInterval22 2030.94 2913 3105 37.5 3680 37 12:35:21 AlarmDelta StageAtTopPerf=17 2055.93 2921 3086 37.5 3696 38 12:39:22 AlarmDelta StageAtTopPerf=18 2172.59 1893 2081 15.2 3444 39 12:40:01 BallonSeat DartonSeatforInterval22 2182.44 1919 2110 15.2 3449 40 12:40:11 BreakFormation BreakFormation 2184.72 4425 4616 15.1 6358 41 12:42:46 AlarmDelta StageAtTopPerf=1 2223.74 3999 4161 15.6 5546 42 12:52:44 AlarmDelta StageAtTopPerf=2 2508 4547 4700 37 5885 43 13:00:49 AlarmDelta StageAtTopPerf=3 2811.17 2941 3138 37.7 4299 44 13:02:09 AlarmDelta StageAtTopPerf=4 2861.37 2740 2949 37.6 4102 45 13:03:52 AlarmDelta StageAtTopPerf=5 2925.97 2624 2844 37.6 4008 46 13:06:45 AlarmDelta StageAtTopPerf=6 3034.35 2521 2748 37.5 3874 47 13:10:23 AlarmDelta StageAtTopPerf=7 3170.71 2527 2763 37.4 3845 48 13:14:12 AlarmDelta StageAtTopPerf=8 3313.4 2426 2662 37.4 3736 49 13:16:55 Other LostSandinHopper 3415.12 2407 2651 37.4 3712 50 13:18:24 AlarmDelta StageAtTopPerf=9 3470.76 2446 2701 37.4 3726 51 13:22:45 AlarmDelta StageAtTopPerf=10 3632.96 2401 2664 37.2 3679 52 13:27:24 AlarmDelta StageAtTopPerf=11 3805.72 2614 2868 37 3722 53 13:29:00 StartFlush StartFlush 3864.8 2736 2962 37.7 3737 54 13:30:46 AlarmDelta StageAtTopPerf=12 3932.15 3092 3411 37.7 3756 55 13:34:22 ISIP ISIP 4063.67 1172 1354 0 3441 56 13:39:21 ShutͲInPressure@5Minutes ShutͲInPressure@5Minutes 4063.67 983 1114 0 3342 57 13:44:24 ShutͲInPressure@10Minutes ShutͲInPressure@10Minutes 4063.67 784 904 0 3287 58 13:49:23 ShutͲInPressure@15Minutes ShutͲInPressure@15Minutes 4063.67 585 701 0 3238 EventLog3.3 ConocoPhillipsͲ3TͲ608 EventLog3.3 80 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Test #1 Test #2 Test #3 Test #4 time (hr:min) -->00:00 01:00 02:00 03:00 04:00 05:00 10:00 15:00 20:00 25:00 30:00 45:00 1:00 1:15 1:30 1:45 2:00 2:15 2:30 2:45 3:00 3:30 4:00 4:30 5:00 5:30 6:00 6:30 Test #1 (cp) -->2469 1852 1185 741 913 864 1086 1234 1284 1337 1417 1257 1150 883 481 241 134 134 0000000000 Dial Reading 100 75 48 30 37 35 44 50 48 50 53 47 43 33 18 9 5 5 Test #2 (cp) -->2808 1658 1498 1471 1230 1257 1765 1765 1712 1738 1524 1471 1605 1150 1070 1043 642 588 535 134 80 0 0 0 0000 Dial Reading 105 62 56 55 46 47 66 66 64 65 57 55 60 43 40 39 24 22 20 5 3 Test #3 (cp) -->0000000000000000000000000000 Dial Reading Test #4 (cp) -->0000000000000000000000000000 Dial Reading 3T-608 Stage(s): Break Test 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 2/25/2025 ConocoPhillips Project No: D. Martinez Hydration Visc: 25 98 Temperature was held at 140 degres for the duration of the test All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.00 Hydration pH: 7.40 Temp 0F PH LOSURF-300D WG-36 CAT3 MO-67 CL-28M BC-140X2 OptiFlo-II OptiFlo-III 98 8.70 1.00 30.00 0.00 0.32 1.00 120 8.80 1.00 30.00 0.00 0.40 1.00 0.25 1.25 0.25 1.25 0.00 1.25 0 500 1000 1500 2000 2500 3000 00:00 02:00 04:00 10:00 20:00 30:00 1:00 1:30 2:00 2:30 3:00 4:00 5:00 6:00Viscosity (cp)Time (min:sec) Prejob Crosslink Break Tests 30# Opti II @ 2.0 and Opti III @ 2.0 30 # Opti II @ 3.0 and Opti III @ 2.0 30 # Opti II @ 2.0 and Opti III @ 2.0 35 # Opti II @ 2.0 and Opti III @ 2.0 Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 PrejobBreakTest 81 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.25 ppg 1 ppg 2 ppg 3 ppg 4 ppg 3T-608 Stage(s): 15 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 3/1/2025 HILCORP Project No: D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.20 Hydration pH: Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III 89 8.70 1.00 1.00 30.00 0.38 1.25 1.25 0 200 400 600 800 1000 1200 1400 1600 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 15 Crosslink Tests Pad 0.5 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Fann15minZone15 82 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.25 ppg 1 ppg 2 ppg 3 ppg 4 ppg 3T-608 Stage(s): 16 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 3/1/2025 HILCORP Project No: D. Martinez Hydration Visc: 25 95 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.20 Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III 89 8.70 1.00 1.00 30.00 0.38 1.25 1.25 0 500 1000 1500 2000 2500 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 16 Crosslink Tests Pad 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone16 83 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 3T-608 Stage(s): 17 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 3/1/2025 HILCORP Project No: D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III 89 8.70 1.00 1.00 30.00 0.38 1.25 1.25 0 200 400 600 800 1000 1200 1400 1600 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 17 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone17 84 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 3T-608 Stage(s): 18 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 3/2/2025 HILCORP Project No: D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III 89 8.70 1.00 1.00 30.00 0.38 1.25 1.25 0 200 400 600 800 1000 1200 1400 1600 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 18 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone18 85 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 3T-608 Stage(s): 19 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 3/2/2025 HILCORP Project No: D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III 89 8.70 1.00 1.00 30.00 0.38 1.25 1.25 0 200 400 600 800 1000 1200 1400 1600 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 19 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone19 86 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 3T-608 Stage(s): 20 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 3/2/2025 HILCORP Project No: D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III 89 8.70 1.00 1.00 30.00 0.38 1.25 1.25 0 200 400 600 800 1000 1200 1400 1600 1800 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 20 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone20 87 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 3T-608 Stage(s): 21 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 3/3/2025 HILCORP Project No: D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III 89 8.70 1.00 1.00 30.00 0.38 1.25 1.25 0 100 200 300 400 500 600 700 800 900 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 21 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone21 88 Company: Well Name: BHST (ºF): Depth: Formation: Analyst:cp @ Lot Number---> Pad 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 3T-608 Stage(s): 22 140 Water Source: CPF3 ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 3/3/2025 HILCORP Project No: D. Martinez Hydration Visc: 24 96 All chemical concentrations below are in gallons per thousand / pounds per thousand Water pH: 7.03 Hydration pH: Temp 0F PH LOSURF-300D CL-28 WG-36 MO-67 Optiflo II Optiflo III 89 8.70 1.00 1.00 30.00 0.38 1.25 1.25 0 500 1000 1500 2000 2500 00:00 01:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 12:00 13:00 14:00 15:00Viscosity (cp)Time (min:sec) Zone 22 Crosslink Tests 0.5 ppg 1 ppg 2 ppg 3 ppg 4 ppg 5 ppg Fluid is broken at 200cp ConocoPhillipsͲ3TͲ608 Zone22 89 Company: Well: SandType DateTested TotalSampleSize SeiveWeight SeiveWeight100.0 g SieveSize BeforeSand Withsand WT.rtn'd %rtn'd% APISpec 12 355 355 0 0.0% 0.00% <0.1% 16 340 346.1 6.1 6.1% 18 303.3 388.5 85.2 85.2% 20 296.4 304.9 8.5 8.5% 25 419.3 419.4 0.1 0.1% 30 281.5 281.5 0 0.0% 40 407.6 407.6 0 0.0% Pan 306.6 306.7 0.1 0.1% 0.10% <1.0% Total: 100 100% ConocoPhillips 3TͲ608 16/20Proppant 2/25/2025 CeramicProppantSieves Sample: 16/20Ͳ2/25/2025 93.80% >/=90% ConocoPhillipsͲ3TͲ608 SandSieveAnalysis 90 Hydraulic Fracturing Fluid Product Component Information Disclosure 12/16/2024 Alaska HARRISON BAY 50-103-20890-00-00 CONOCOPHILLIPS 3T 608 -150.26542197 70.42076262 NAD83 none Oil 5162 945011 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 SEAWATER (SG 8.52) Operator Base Fluid Density = 8.52 BC-140 X2 Halliburton Initiator BE-6(TM) Bactericide Halliburton Microbiocide CL-28M CROSSLINKER Halliburton Crosslinker LoSurf-300D Halliburton Non-ionic Surfactant MO-67 Halliburton pH Control OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker WG-36 GELLING AGENT Halliburton Gelling Agent Ceramic Proppant - Wanli Wanli Proppant SAND, COMMON BROWN 100 MESH Halliburton Proppant Flow Insurance Copper Patina Energy Tracer Ingredients Water 7732-18-5 100.00%77.22054%8051494 Corundum 1302-74-5 65.00%14.16316%1476740 Mullite 1302-93-8 45.00%9.80527%1022359 Sodium chloride 7647-14-5 5.00%3.86103%402575 Crystalline silica, quartz 14808-60-7 100.00%0.46822%48820 Guar gum 9000-30-0 100.00%0.27766%28951 Water 7732-18-5 100.00%0.08495%8858 Borate salts Proprietary 60.00%0.05546%5783 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%0.04142%4319 Ammonium persulfate 7727-54-0 100.00%0.04028%4200 Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.02071%2160 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Heavy aromatic petroleum naphtha 64742-94-5 30.00%0.02071%2160 Monoethanolamine borate 26038-87-9 100.00%0.02046%2134 Oxylated phenolic resin Proprietary 30.00%0.01208%1260 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Sodium hydroxide 1310-73-2 30.00%0.00701%731 Oxyalkylated phenolic resin Proprietary 10.00%0.00690%720 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Ethylene glycol 107-21-1 30.00%0.00614%641 Potassium chloride 7447-40-7 5.00%0.00462%482 Inorganic mineral 1317-65-3 5.00%0.00462%482 Flow Insurance Copper Proprietary 100.00%0.00461%481 Patina Energy Product Stewardship test@patinae nergy.com 7205324886 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00%0.00345%360 Naphthalene 91-20-3 5.00%0.00345%360 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00178%186 Polymer Proprietary 1.00%0.00092%97 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Inorganic mineral Proprietary 1.00%0.00092%97 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Gluteraldehyde 111-30-8 1.00%0.00092%97 Calcium magnesium carbonate 16389-88-1 1.00%0.00092%97 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00069%72 Sodium chloride 7647-14-5 1.00%0.00023%25 C.I. pigment Orange 5 3468-63-1 1.00%0.00022%23 Methanesulfonic acid, 1-hydroxy-, sodium salt 870-72-4 0.10%0.00009%10 Sodium bisulfate 7681-38-1 0.10%0.00009%10 2,7-Naphthalenedisulfonic acid, 3- hydroxy-4-[(4-sulfor-1- naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00002%3 Magnesium nitrate 10377-60-3 0.01%0.00001%1 Magensium chloride 7786-30-3 0.01%0.00001%1 5-Chloro-2-methyl-3(2H)- Isothaiazolone 26172-55-4 0.01%0.00001%1 2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00001%1 * 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 1.4 Allcomponentinformationlistedwasobtainedfromthesupplier’sMaterialSafetyDataSheets(MSDS).Assuch,theOperatorisnotresponsibleforinaccurateand/orincompleteinformation.AnyquestionsregardingthecontentoftheMSDSshouldbedirectedtothesupplier whoprovidedit.TheOccupationalSafetyandHealthAdministration’s(OSHA)regulationsgovernthecriteriaforthedisclosureofthisinformation.PleasenotethatFederalLawprotects"proprietary","tradesecret",and"confidentialbusinessinformation"andthecriteriaforhow thisinformationisreportedonanMSDSissubjectto29CFR1910.1200(i)andAppendixD. 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: Hydraulic Fracturing Fluid Product Component Information Disclosure 3/3/2025 Alaska HARRISON BAY 50-103-20890-00-00 CONOCOPHILLIPS 3T 608 -150.26542197 70.42076262 NAD83 none Oil 5162 626337.85 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 SEAWATER (SG 8.52) Operator Base Fluid Density = 8.52 BC-140 X2 Halliburton Initiator BE-6(TM) Bactericide Halliburton Microbiocide CL-28M CROSSLINKER Halliburton Crosslinker LoSurf-300D Halliburton Non-ionic Surfactant MO-67 Halliburton pH Control OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker WG-36 GELLING AGENT Halliburton Gelling Agent Ceramic Proppant - Wanli Wanli Proppant SAND, COMMON BROWN 100 MESH Halliburton Proppant Ingredients Water 7732-18-5 95.00%73.80623%5336399 Corundum 1302-74-5 60.00%12.87388%930818 Mullite 1302-93-8 40.00%8.58259%620546 Sodium chloride 7647-14-5 5.00%3.88454%280864 Crystalline silica, quartz 14808-60-7 100.00%0.33673%24347 Guar gum 9000-30-0 100.00%0.27494%19879 Water 7732-18-5 100.00%0.09736%7040 Borate salts Proprietary 60.00%0.05361%3876 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%0.04352%3147 Ammonium persulfate 7727-54-0 100.00%0.02351%1700 Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.02176%1574 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Heavy aromatic petroleum naphtha 64742-94-5 30.00%0.02176%1574 Monoethanolamine borate 26038-87-9 100.00%0.02136%1545 Sodium hydroxide 1310-73-2 30.00%0.01120%811 Oxyalkylated phenolic resin Proprietary 10.00%0.00725%525 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Oxylated phenolic resin Proprietary 30.00%0.00705%510 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Ethylene glycol 107-21-1 30.00%0.00641%464 Potassium chloride 7447-40-7 5.00%0.00447%323 Inorganic mineral 1317-65-3 5.00%0.00447%323 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00%0.00363%263 Naphthalene 91-20-3 5.00%0.00363%263 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00180%130 Calcium magnesium carbonate 16389-88-1 1.00%0.00089%65 Polymer Proprietary 1.00%0.00089%65 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 Gluteraldehyde 111-30-8 1.00%0.00089%65 Inorganic mineral Proprietary 1.00%0.00089%65 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871-6226 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00073%53 Sodium chloride 7647-14-5 1.00%0.00037%28 C.I. pigment Orange 5 3468-63-1 1.00%0.00012%9 Methanesulfonic acid, 1-hydroxy-, sodium salt 870-72-4 0.10%0.00009%7 Sodium bisulfate 7681-38-1 0.10%0.00009%7 2,7-Naphthalenedisulfonic acid, 3- hydroxy-4-[(4-sulfor-1- naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00002%2 Magnesium nitrate 10377-60-3 0.01%0.00001%1 5-Chloro-2-methyl-3(2H)- Isothaiazolone 26172-55-4 0.01%0.00001%1 2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00001%1 Magensium chloride 7786-30-3 0.01%0.00001%1 * 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 Allcomponentinformationlistedwasobtainedfromthesupplier’sMaterialSafetyDataSheets(MSDS).Assuch,theOperatorisnotresponsibleforinaccurateand/orincompleteinformation.AnyquestionsregardingthecontentoftheMSDSshouldbedirectedtothesupplier whoprovidedit.TheOccupationalSafetyandHealthAdministration’s(OSHA)regulationsgovernthecriteriaforthedisclosureofthisinformation.PleasenotethatFederalLawprotects"proprietary","tradesecret",and"confidentialbusinessinformation"andthecriteriaforhow thisinformationisreportedonanMSDSissubjectto29CFR1910.1200(i)andAppendixD. 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: Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 1] REPORT DATE: [ 12/4/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 403,964.68 Cumulative Cost (Cost) 403,964.68 Weather Temperature (°F) Road Condition Wind Last 24hr Summary HAL ASSIST WITH MONITORING PSI'SFOR ARSENAL DISK BURST AND ALPHA SLEEVE SHIFT 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 06:00 07:00 1.00 TRAV P CREW TRAVEL FROM KCC TO 3T 07:00 16:00 9.00 RURD P MONITOR PSI FOR ARSENAL DISK/ALPHA SLEEVE SHIFT. SPOT HP, HEATERS ON WATER MANIFOLD, RIG UP HP TO MANIFOLD TRAILER. SPOT DATA VAN AND TOOL TRAILER 16:00 17:00 1.00 TRAV P CREW TRAVEL 3T TO KCC Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 1] REPORT DATE: [ 12/4/2024] Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 2] REPORT DATE: [ 12/5/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 37,399.20 Cumulative Cost (Cost) 441,363.88 Weather Temperature (°F) Road Condition Wind Last 24hr Summary SPOT HEATERS, TARP BACKSIDE EQUIPMENT, RIG UP 4" TREATING LINE 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 06:00 07:00 1.00 TRAV P CREW TRAVEL KCC TO 3T 07:00 18:00 11.00 RURD P TARPED UP BACKSIDE EQUIPMENT, SPOT HEATERS, MIRU 4" TREATING LINES, SPOT SAND EQUIPMENT, LOAD WATER, LOAD SAND 18:00 23:59 5.99 RURD P RUN HOSES FOR EQUIPMENT, CONTINUE TO LOAD WATER Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 2] REPORT DATE: [ 12/5/2024] Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 3] REPORT DATE: [ 12/6/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 41,299.20 Cumulative Cost (Cost) 482,663.08 Weather Temperature (°F) Road Condition Wind Last 24hr Summary CONTINUE LOADING WATER, RIG UP HOSES TO EQUIPMENT, CONTINUE RIG UP OF 4" IRONS 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P LOAD WATER, RECEIVE POTABLE WATER FOR CHEMICALS, START WATER TESTING 06:00 18:00 12.00 RURD P CONTINUE LOADING WATER, LOADING SAND, CONTINUE TO RUN 4" IRONS, RIG UP HOSES ON EQUIPMENT, BROUGHT OUT CHEM TRAILERS 18:00 23:59 5.99 RURD P LOADING WATER/SAND Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 3] REPORT DATE: [ 12/6/2024] Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 4] REPORT DATE: [ 12/7/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 41,299.20 Cumulative Cost (Cost) 523,962.28 Weather Temperature (°F) Road Condition Wind Last 24hr Summary HAL FUNCTION TEST EQUIPMENT/CHECK COMMS, SPOT CHEMICAL FLOAT, WATER TESTING. UNABLE TO RIG UP AROUND WELL DUE TO SPACE CONSTRAINTS WITH RIG CEMENTING 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P VERIFY VALVE OPERATION ON MANIFOLD TRAILER, SPOT FUEL TRUCK,MIX CHEMICALS 06:00 18:00 12.00 RURD T UNABLE TO RIG UP AROUND WELL OR NIPPLE UP DART LAUNCER DUE TO RIG CEMENTING, NO SPACE FOR EQUIPMENT. FUNCTION TEST EQUIPMENT/VERIFY COMMS, MIX CHEMICALS, CONTINUE WATER TESTING 18:00 23:59 5.99 Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 4] REPORT DATE: [ 12/7/2024] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 5] REPORT DATE: [ 12/8/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 51,288.89 Cumulative Cost (Cost) 575,251.17 Weather Temperature (°F) Road Condition Wind Last 24hr Summary RIG UP HARD LINE AROUND WELL, NIPPLE UP DART LAUNCHER, SPOT TANKS IN FRONT YARD, CHECK OVER EQUIPMENT READINESS 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P MIX CHEMICALS, COMPLETE WATER TESTING 06:00 18:00 12.00 RURD P FINISH HARDLINE RIG UP AROUND WELL, NIPPLE UP DART LAUNCHER, SPOT TANKS IN FRON YARD, STAGE SAND NEAR SAND EQUIPMENT 18:00 23:59 5.99 RURD P CONTINUE MIXING CHEMICAL TOTES, VERIFY EQUIPMENT READINESS Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 5] REPORT DATE: [ 12/8/2024] Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 6] REPORT DATE: [ 12/9/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 869,197.58 Cumulative Cost (Cost) 1,444,448.75 Weather Temperature (°F) Road Condition Wind Last 24hr Summary STIMULATE STAGE 1- 3 PER DESIGN w/ 9213 LBS OF 100 MESH & 599261 LBS OF 16/20 PROPPANT UP TO 7 PPG. TOTAL PROP 608277, 7538 BBL FLUID PUMPED (PATINA TRACER ADDED PER SCHEDULE) 24hr Forecast General Remarks INITIAL T/I/O=400/23/208 FINAL T/I/O=1177/560/404 ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:30 6.50 RURD P RIG UP ACID PUMP IN FRONT YARD, DOUBLE CHECK ALL HARDLINE CONNECTIONS, RIG UP CHEMICAL HOSES. 06:30 10:30 4.00 WAIT P PJSM, PRIME(LEAK ON STANDPIPE DOWN FROM 0748 - 0840). RESUME PRIMING. TEST ePRV'S TO 500PSI, LEAK FOUND ON CHIKSAN AT MISSILE AT 1000PSI - BLED DOWN AND VAC OUT LINE. (0915 -0940) RESUME PRIMING. PT TO MAX -9493, PT 5 MIN - 9343 PSI GOOD TEST. HAL LOAD CHEMICALS ON BLENDER 10:30 13:00 2.50 PUMP P EQUALIZE WELL TO 740PSI, OPENING AT 400. ESTABLISH RATE TO 15BPM, PERFORM SRT IN 1BBL INCREAMENTS. TOTAL CLEAN VOLUME PUMPED 2878 BBL, TOTAL PROPPANT PLACED 200000 100 MESH 3624 LB, 16/20 196376 LB, AVG PSI 3468, AVG RATE 33.7 BPM HAD TO DROP RATE 2 TIME THROUGH STAGE DUE TO WATER ISSUES ON TANKS, CUT SAND. WORK BACK INTO STAGE TO GET BACK ON SCHEDULE. 13:00 15:00 2.00 PUMP P LAUNCHED DART 1 FOR STAGE 2 @ 3057 JSV, LANDED 19 BBL EARLY @ 3349 JSV, DIFFERENTIAL 3615 PSI SURFACE, 3526 PSI BH, TOTAL CLEAN VOLUME PUMPED 2727 BBL, TOTAL PROPPANT PLACED 202720 100 MESH 2773 LB, 16/20 199947 LB, AVG PSI 3746, AVG RATE 33.6 BPM PERFORMED MINI-FRAC, SHUT MONITORED PSI FOR 1 HR 15:00 16:30 1.50 PUMP P LAUNCHED DART 2 FOR STAGE 3 @ 5998 JSV, LANDED 9 BBL EARLY @ 6296 JSV, SURFACE DIFFERENTIAL 3457 PSI, 3225 PSI BH, TOTAL CLEAN VOLUME PUMPED 1996 BBL, TOTAL PROPPANT PLACED 205754, 100 MESH 2816 LB, 16/20 202938 LB, AVG PSI 4004, AVG RATE 33.9 BPM 16:30 18:30 2.00 PUMP P ISIP-3390 PSI 5 MIN-3352 PSI 10 MIN-3295 PSI 15 MIN-3252 PSI LRS FREEZE PROTECT TUBING - 30BBL 18:30 23:59 5.49 RURD P LOAD SAND/WATER, EQUIPMENT MAINTENANCE Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 30.0 30.0 SEAWATER 7,538.0 7,538.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 6] REPORT DATE: [ 12/9/2024] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Stimulation Intervals Interval Number Start Date End Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Volume Clean Total (bbl) Volume Slurry Total (bbl) 1 12/9/2024 10:23 12/9/2024 13:02 0.0 0.0 204,000.0 199,932.0 2,887.29 3,099.68 2 12/9/2024 13:02 12/9/2024 15:27 0.0 0.0 204,000.0 202,720.0 2,726.17 2,941.50 3 12/9/2024 15:27 12/9/2024 16:23 0.0 0.0 204,000.0 205,754.0 1,996.29 2,214.84 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 7] REPORT DATE: [ 12/10/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 328,430.86 Cumulative Cost (Cost) 1,772,879.61 Weather Temperature (°F) Road Condition Wind Last 24hr Summary STIMULATE STAGE 4 PER DESIGN w/ 4466 LBS OF 100 MESH & 199855 LBS OF 16/20 PROPPANT, 204321 TOTAL PROPPANT UP TO 7 PPG. 2171 BBL FLUID PUMPED JOB ON HOLD DUE TO HES PUMP ISSUES 24hr Forecast General Remarks INITIAL T/I/O=590/0/183 FINAL T/I/O=1167/588/522 ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 WAIT P LOAD SAND/WATER, COMPLETE MAINTENANCE ON HP, BEGIN WATER TESTING 06:00 12:30 6.50 WAIT T WAIT ON WATER JOB VOLUME THE DAYS PLANNED STAGES PRIME EQUIPMENT/TEST ePRV'S TO 500 PSI, PT MAX - 9528 PT 5 MIN - 9399 GOOD TEST BUCKET TEST, HIGH/LOW CAL 12:30 14:15 1.75 PUMP P EQUALIZE TO 1292/OPEN 590, ESTABLISH INJ TO 15 BPM. LAUNCHED DART 3 FOR STAGE 4 @ 32 JSV, LANDED 10 BBL EARLY @ 321 JSV, SURFACE DIFFERENTIAL 3505 PSI, 3474 PSI BH, TOTAL CLEAN VOLUME PUMPED 2171 BBL, TOTAL SLURRY VOLUME 2388 BBL TOTAL PROPPANT PLACED 204321, 100 MESH 4466 LB, 16/20 199855 LB, AVG PSI 4130, AVG RATE 32.5 BPM ISIP-3385 PSI 5 MIN-3303 PSI 10 MIN-3261 PSI 15 MIN-3220 PSI 30BBL DIESEL FREEZE PROTECT 14:15 23:59 9.74 WAIT T SHUT DUE TO HP ISSUES, PUMP NEEDS PWR END HOSE, PUMP NEEDS SUCTION MANIFOLD, REST NEED MAINTENANCE. UNABLE TO ACHIEVE 37 BPM, CAPPED AT 24 BPM. CONTINUE TO LOAD WATER/SAND Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 30.0 60.0 SEAWATER 2,171.0 9,709.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 7] REPORT DATE: [ 12/10/2024] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Stimulation Intervals Interval Number Start Date End Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Volume Clean Total (bbl) Volume Slurry Total (bbl) 4 12/10/2024 12:49 12/10/2024 14:15 0.0 0.0 204,000.0 204,282.0 2,262.98 2,480.01 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 8] REPORT DATE: [ 12/11/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 1,268,427.06 Cumulative Cost (Cost) 3,041,306.67 Weather Temperature (°F) Road Condition Wind Last 24hr Summary STIMULATE STAGE 5 - 10 (SKIPPING #6) PER DESIGN w/ 18384 LBS OF 100 MESH & 999548 LBS OF 16/20 PROPPANT UP TO 7 PPG. 9189 BBL FLUID PUMPED 24hr Forecast General Remarks INITIAL T/I/O=630/0/126 FINAL T/I/O=1042/544/466 ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD T HAL CONTINUE PUMP MAINTENANCE CONTINUE TO LOAD WATER/SAND, BEGIN WATER TESTING 06:00 10:30 4.50 WAIT P WAIT ON VAC TRUCK TO RETURN FROM OFFLOAD BEFORE STARTING. VAC TRUCK ARRIVE FROM DISPOSAL AT 0900. PRIME, TEST ePRV'S TO 500 PSI PT MAX-9544 PSI PT 5 MIN-9370 PSI GOOD TEST MIX GEL/LOAD CHEMCIALS ON BLENDER, VERIFY DARTS AND LOAD INTO REVOLVER 10:30 12:00 1.50 PUMP P EQUALIZE TO 1219 PSI, OPEN AT 630 PSI LAUNCHED DART 4 FOR STAGE 5 @ 293 JSV, LANDED 12 BBL EARLY @ 321 JSV, SURFACE DIFFERENTIAL 3397 PSI, BHP DIFFERENTIAL 3231 PSI, TOTAL CLEAN VOLUME PUMPED 2219 BBL, TOTAL PROPPANT PLACED 204295 100 MESH 3702 LB, 16/20 200593 LB, AVG PSI 4132, AVG RATE 33.4 BPM PERFORMED DFIT AT 12 BPM, SHUT IN MONITOR PSI FOR 30 MIN 12:00 13:15 1.25 PUMP P LAUNCHED DART 6 FOR STAGE 7 @ JSV, LANDED 7 BBL EARLY @ 2713 JSV, SURFACE DIFFERENTIAL 3418 PSI, BHP DIFFERENTIAL 3428 PSI, TOTAL CLEAN VOLUME PUMPED 1715 BBL, TOTAL PROPPANT PLACED 203135, 100 MESH 3436 LB, 16/20 199699 LB, AVG PSI 3570, AVG RATE 34.9 BPM 13:15 14:15 1.00 PUMP P LAUNCHED DART 7 FOR STAGE 8 @ 4379 JSV, LANDED 14 BBL EARLY @ 4634 JSV, SURFACE DIFFERENTIAL 3595 PSI, BHP DIFFERENTIAL 3579 PSI, TOTAL CLEAN VOLUME PUMPED 1655 BBL, TOTAL PROPPANT PLACED 203693 LB, 100 MESH 3866 LB, 16/20 199827 LB, AVG PSI 3478, AVG RATE 34.8 BPM 14:15 15:00 0.75 PUMP P LAUNCHED DART 8 FOR STAGE 9 @ 6248 JSV, LANDED 13 BBL EARLY @ 6496 JSV, SURFACE DIFFERENTIAL 3443 PSI, BHP DIFFERENTIAL 3154 PSI, TOTAL CLEAN VOLUME PUMPED 1677 BBL, TOTAL PROPPANT PLACED 202966, 100 MESH 3462 LB, 16/20 199504 LB, AVG PSI 3323, AVG RATE 35.3 BPM 15:00 17:30 2.50 PUMP P LAUNCHED DART 9 FOR STAGE 10 @ 8141 JSV, LANDED 16 BBL EARLY @ 8379 JSV, SURFACE DIFFERENTIAL 3484 PSI, BHP DIFFERENTIAL 3291 PSI, TOTAL CLEAN VOLUME PUMPED 1908 BBL, TOTAL PROPPANT PLACED 203808,100 MESH 3918 LB, 16/20 199890 LB, AVG PSI 3560, AVG RATE 35.8 BPM ISIP-3238PSI 5 MIN-3153 PSI 10 MIN-3090 PSI 15 MIN-3043 PSI TUBING FREEZE PROTECT 30BBL 17:30 23:59 6.49 PUMP P LOAD WATER/SAND, EQUIPMENT MAINTENANCE Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 8] REPORT DATE: [ 12/11/2024] Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 30.0 90.0 SEAWATER 9,189.0 18,898.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Stimulation Intervals Interval Number Start Date End Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Volume Clean Total (bbl) Volume Slurry Total (bbl) 5 12/11/2024 10:23 12/11/2024 12:14 0.0 0.0 204,000.0 204,246.2 2,248.43 2,465.43 7 12/11/2024 12:14 12/11/2024 13:10 0.0 0.0 204,000.0 203,055.5 1,715.14 1,930.89 8 12/11/2024 13:10 12/11/2024 14:05 0.0 0.0 204,000.0 203,499.1 1,654.98 1,871.27 9 12/11/2024 14:05 12/11/2024 14:59 0.0 0.0 204,000.0 202,933.2 1,676.55 1,892.16 10 12/11/2024 14:59 12/11/2024 16:01 0.0 0.0 204,000.0 203,773.0 1,939.12 2,155.60 Page 1/1 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 9] REPORT DATE: [ 12/12/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 46,094.00 Cumulative Cost (Cost) 3,087,400.67 Weather Blizzard Temperature (°F) Road Condition Poor Wind Last 24hr Summary DOWN FOR WEATHER-PHASE 3 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 23:59 23.99 WAIT T DOWN FOR WEATHER - PHASE 3 Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 90.0 SEAWATER 18,898.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/1 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 10] REPORT DATE: [ 12/13/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 46,094.00 Cumulative Cost (Cost) 3,133,494.67 Weather Blizzard Temperature (°F) Road Condition Poor Wind Last 24hr Summary DOWN FOR WEATHER-PHASE 3 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 23:59 23.99 WAIT T DOWN FOR WEATHER - PHASE 3 Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 90.0 SEAWATER 18,898.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 11] REPORT DATE: [ 12/14/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 49,544.00 Cumulative Cost (Cost) 3,183,038.67 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary CLEAN UP AFTER PHASE CONDITIONS ON 3T AND 3J, START AND FUNCTION TEST ALL EQUIPMENT RESUME HAULING SW 3J TO 3T. 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:30 6.50 WAIT T LOIL GIVEN PERMISSION TO BE ON 3T AND ASSIST WITH AREA CLEAN UP WITH FRAC LOADERS 06:30 07:30 1.00 TRAV T CREW TRAVEL KCC TO 3T 07:30 16:30 9.00 WAIT T OK GIVEN BY OPS TO BEGIN AREA CLEAN UP AFTER PHASE 3. SHOVEL OUT AROUND EQUIPMENT, TANK FARM, SAND AREA. LOADER SENT TO 3J TO ASSIST WITH PAD CLEAN UP TO ALLOW FOR WATER LOADING. START EQUIPMENT AND FUNCTION TEST 16:30 23:59 7.49 WAIT T LOAD WATER, WATER TESTING Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 90.0 SEAWATER 18,898.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 11] REPORT DATE: [ 12/14/2024] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 12] REPORT DATE: [ 12/15/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 407,008.30 Cumulative Cost (Cost) 3,590,046.97 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary STIMULATE STAGE 11- 12 PER DESIGN w/ 7891 LBS OF 100 MESH & 399545 LBS OF 16/20 PROPPANT UP TO 7 PPG. 4241 BBL FLUID PUMPED 24hr Forecast General Remarks INITIAL T/I/O=548/0/112 FINAL T/I/O=1121/461/624 ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 WAIT P LOAD WATER-EXPRO ISSUES ON 3J, HEATERS RAN OUT OF FUEL/ICE PLUGS IN HARDLINE, LATE START ON FLOWING WATER. WATER TESTING, SHOVEL OUT TANK FARM, CHECK EQUIPMENT FLUIDS/START EQUIPMENT 06:00 12:00 6.00 WAIT P PJSM, WAIT ON REMAINING WATER PRIME, TEST ePRV'S TO 500 PSI PT MAX - 9478 PT 5 MIN - 9255 GOOD TEST 12:00 14:30 2.50 PUMP P EQUALIZE TO 1130 PSI, OPEN AT 548 PSI ESTABLISH RATE TO 15 BPM. LAUNCHED DART 10 FOR STAGE 11 @ 28 JSV, LANDED 12 BBL EARLY @ 262 JSV, SURFACE DIFFERENTIAL 3621 PSI, BHP DIFFERENTIAL 3535 PSI, PERFORMED DFIT AT 20 BPM, SHUT IN MONITOR PSI FOR 45 MIN, TOTAL CLEAN VOLUME PUMPED 2326 BBL, TOTAL PROPPANT PLACED 204697 LB, 100 MESH 3555 LB, 16/20 201142 LB, AVG PSI 3366, AVG RATE 36.0 BPM 14:30 16:00 1.50 PUMP P LAUNCHED DART 11 FOR STAGE 12 @ 2506 JSV, LANDED 17 BBL EARLY @ 2728 JSV, SURFACE DIFFERENTIAL 3761 PSI, BHP DIFFERENTIAL 3679 PSI, TOTAL CLEAN VOLUME PUMPED 1979 BBL, TOTAL PROPPANT PLACED 202739 LB, 100 MESH 4336 LB, 16/20 198403 LB, AVG PSI 3459, AVG RATE 36.2 BPM 16:00 17:00 1.00 PUMP P ISIP-3331 PSI 5 MIN-3275PSI 10 MIN-3244 PSI 15 MIN-3218 PSI FREEZE PROTECT TUBING -30BBL 17:00 23:59 6.99 DMOB P SUCK OUT FRAC TANKS, VAC OUT EQUIPMENT, BEGIN RIG DOWN. Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 30.0 120.0 SEAWATER 4,241.0 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 12] REPORT DATE: [ 12/15/2024] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Stimulation Intervals Interval Number Start Date End Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Volume Clean Total (bbl) Volume Slurry Total (bbl) 11 12/15/2024 11:53 12/15/2024 13:58 0.0 0.0 204,000.0 204,543.1 2,319.67 2,537.09 12 12/15/2024 13:58 12/15/2024 15:00 0.0 0.0 204,000.0 202,707.2 1,978.83 2,194.22 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 13] REPORT DATE: [ 12/16/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 46,472.10 Cumulative Cost (Cost) 3,636,519.07 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary RIG DOWN IRON AROUND WELL, RIG DOWN DART LAUNCHER, VAC OUT AND REMOVE BLEED/IA OA TANKS 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 DMOB P CONTINUE RIG DOWN, VAC OUT FRAC TANKS 06:00 12:00 6.00 WAIT T WAIT ON VAC TRUCKS TO OFFLOAD AT WATER RECYCLE AND RETURN TO PAD 12:00 18:00 6.00 DMOB P RIG DOWN FRONT YARD IRONS, RIG DOWN DART LAUNCHER, RDMO BLEED/ IA OA TANKS 18:00 23:59 5.99 DMOB P CONTINUE TO VAC OUT FRAC TANKS, RIG DOWN EQUIPMENT Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 13] REPORT DATE: [ 12/16/2024] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 14] REPORT DATE: [ 12/17/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 19,769.60 Cumulative Cost (Cost) 3,656,288.67 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary CONTINUE TO VAC OUT FRAC TANKS, DELAYS DUE TO OFFLOAING AT WATER RECYCLE. VAC OUT AND MOVE HARDLINE FOR RIG MOVE 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 WAIT T WAIT ON TRUCKS TO BE OFFLOADED AT DISPOSAL TO VAC OUT FRAC TANK BOTTOMS 06:00 10:00 4.00 WAIT T VAC TRUCKS HELD UP AT WATER RECYLCE. CONTINUE TO HEAT TANKS TO ALLOW BOTTOMS TO BE CLEANED UP 10:00 18:00 8.00 DMOB P VAC TRUCKS ARRIVE TO 3T, CONTINUE TO EMPTY TANKS. VAC OUT/RIG DOWN 4" HARDLINE FOR RIG MOVE 18:00 23:59 5.99 WAIT T WAIT ON VAC TRUCKS TO RETURN FROM DISPOSAL TO CLEAN UP TANK BOTTOMS Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 14] REPORT DATE: [ 12/17/2024] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 15] REPORT DATE: [ 12/18/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 17,365.20 Cumulative Cost (Cost) 3,673,653.87 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary HEAT REMAINING FRAC TANKS TO ALLOW FOR BOTTOMS TO BE VAC'D OUT. DUE TO LONG DELAYS AT WATER RECYLCE, TANKS HAVE BEEN FREEZING. 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 09:00 9.00 WAIT T DELAYS OFFLOADING VAC TRUCKS AT DISPOSAL/ NO NIGHT SHIFT 09:00 18:00 9.00 DMOB P TRUCKS ARRIVE FROM DISPOSAL, FINISH CLEANING UP TANK BOTTOMS. HEAT ePRV TANK AND VAC OUT. 18:00 19:00 1.00 TRAV P CREW TRAVEL 3T TO KCC Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 15] REPORT DATE: [ 12/18/2024] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 16] REPORT DATE: [ 12/19/2024] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 47,226.91 Cumulative Cost (Cost) 3,720,880.78 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary BREAK TANK FARM APART, MOVE 10 TANKS FROM RIG SIDE OF FARM TO OPPOSITE SIDE TO ALLOW FOR RIG MOVE 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile KOESTER, GREG Frac Supervisor 814-746-0764 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 06:00 07:00 1.00 TRAV P CREW TRAVEL KCC TO 3T 07:00 18:00 11.00 RURD P BREAK DOWN AND MOVE FRAC TANKS FOR THE RIG MOVE FROM 3T-612 TO 3T- 616. 18:00 19:00 1.00 TRAV P CREW TRAVEL 3T TO KCC Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 16] REPORT DATE: [ 12/19/2024] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 17] REPORT DATE: [ 2/18/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 18,300.00 Cumulative Cost (Cost) 3,739,180.78 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary LOIL, TANK FARM PREP AND BUILD 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 CHERRY, JACOB Supervisor 907-953-9294 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P BUILDING TANK FARM CONTAINMENT 06:00 18:00 12.00 RURD P SPOTTED AND RIGGED IN FRAC TANKS 18:00 23:59 5.99 RURD P ANCILLARY EQUIPMENT MOVEMENT FROM CD5 Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 17] REPORT DATE: [ 2/18/2025] Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 18] REPORT DATE: [ 2/19/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 18,300.00 Cumulative Cost (Cost) 3,757,480.78 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary LOIL, CONTINUE TANK FARM BUILD HAL / LOIL EMPTY BESSER HAL, CONTINUE EQUIPMENT MOVE FROM ALPINE 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 CHERRY, JACOB Supervisor 907-953-9294 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P CONTINUED TANK FARM BUILD. 06:00 10:00 4.00 RURD P CONTINUED TANK FARM BUILD. TRANSPORTING EQUIPMENT FROM ALPINE 10:00 23:59 13.99 RURD P STARTED THE PROPPANT TRANSFER PROCESS FROM THE DOWNED BESSER TO BULKERS, CONTINUED EQUIPMENT TRANSPORT FROM ALPINE. Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 18] REPORT DATE: [ 2/19/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 19] REPORT DATE: [ 2/20/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 18,300.00 Cumulative Cost (Cost) 3,775,780.78 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary LOIL, COMPLETED TANK FARM HAL, EQUIPMENT MOVE FROM ALPNE COMPLETED 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 CHERRY, JACOB Supervisor 907-953-9294 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P COMPLETED SUPPORT EQUIPMENT MOVE FROM ALPINE 06:00 18:00 12.00 RURD P HAL, COMPLETED EQUIPMENT MOVE FROM ALPINE, LOIL COMPLETED FRAC TANK FARM BUILD 18:00 23:59 5.99 LOIL PROPPANT REMOVAL FROM CONTAINERS TO STAGING Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 19] REPORT DATE: [ 2/20/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 20] REPORT DATE: [ 2/21/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 18,300.00 Cumulative Cost (Cost) 3,794,080.78 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary EXPRO, SETUP WATER LOADING STATIONS ON 3J 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 CHERRY, JACOB Supervisor 907-953-9294 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 18:00 18.00 RURD P EXPRO,RIG IN WATER LOADING STATIONS ON 3J HAL, CREW SWAP LOIL, CREW SWAP 18:00 23:59 5.99 RURD EXPRO, WRAPPING LINES, THAWING VALVES, PREPPING FOR MORNING TRUCK LOADING Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 20] REPORT DATE: [ 2/21/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 21] REPORT DATE: [ 2/22/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 21,800.00 Cumulative Cost (Cost) 3,815,880.78 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary WATER LOADING, SPOTTING FRAC EQUIPMENT 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P LOIL, SPOTTED IN WATER HEATER, SEAMED/BERMED CONTAINMENT, FUNCTION TESTED UNIT 06:00 13:00 7.00 RURD P LOIL, EXPRO AES, LOADING STATION AT 3J FROZE UP, DIVERTED TRUCKS TO CPF2 FOR WATER LOADING, FIRST TRUCK RECEIVED @9.30 AM, PROBLEM RESOVED BY 11, BACK TO 3J, 13:00 19:00 6.00 RURD P HAL, PAD MAINTENANCE COMPLETED (LARGE SNOW PILE APPEARED) STRETCHED CONTAINMENT SPOTTED FRAC EQUIPMENT. LOIL, EXPRO, AES, HAL, CONTINUED LOADING/HEATING WATER, REPORT CAME IN LOADING WAS SLOW, FLOW RATE AT 3J WAS @ 2BPM, RAISED IT TO 6BPM, TARGET IS A TRUCK EVERY 45 MINUTES, 19:00 23:59 4.99 RURD P LOIL, EXPRO, AES, HAL, CONTINUE HAULING/HEATING WATER Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 21] REPORT DATE: [ 2/22/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 22] REPORT DATE: [ 2/23/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 24,681.39 Cumulative Cost (Cost) 3,840,562.17 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary WATER LOADING, RIGGING IN IRON,SPOTTING SAND EQUIPMENT 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P WATER LOADING/ HEATING 06:00 11:00 5.00 RURD P WATER LOADING/ HEATING, COMPLETRED SPOTTING EQUIPMENT 11:00 19:00 8.00 RURD P WATER LOADING/ HEATING, STARTED RUNNING HARD LINE, SPOTTED SAND EQUIPMENT 19:00 23:59 4.99 RURD P WATER LOADING/ HEATING Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 22] REPORT DATE: [ 2/23/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 23] REPORT DATE: [ 2/24/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 43,281.39 Cumulative Cost (Cost) 3,883,843.56 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary WATER LOADING/ HEATING COMPLETED, PROPPANT LOADING IN PROGRESS, FRAC RIG UP IN PROGRESS 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P CONTINUE LOADING / HEATING WATER,CONTINUED LOADING PROPPANT 06:00 18:00 12.00 RURD P CONTINUE LOADING / HEATING WATER,CONTINUED LOADING PROPPANT 18:00 20:00 2.00 RURD P WATER LOADING/ HEATING COMPLETE, 20:00 23:59 3.99 RURD P SPOT 3" PRV TANK RUN ePRV LINE Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 23] REPORT DATE: [ 2/24/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 24] REPORT DATE: [ 2/25/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 75,541.39 Cumulative Cost (Cost) 3,959,384.95 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary CONTINUED FRAC RIG UP, PROPPANT LOADING COMPLETED, PROPPANT STAGING IN PROGRESS, 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile CAMPBELL, JAMES Frac Supervisor 661-203-1472 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P LOIL,ROLLING TANKS, HEATING UP TO DESIRED TEMP 06:00 06:09 0.15 RURD T WHILE ROLLING TANKS A TANK VALVE WAS LEFT OPEN OVERFILLING THE TANK LEFT OPEN, TOTAL SPILL 50BBL, UN REPORTABLE DUE TO SEA WATER PROXIMITY. SECURITY CONTACTED, HSE NOTIFIED, ACS DISPATCHED FOR SPILL RESPONSE. 06:09 18:09 12.00 RURD P HAL, CONTINUE IRON RIG UP. 18:09 23:59 5.84 RURD P LOIL CONTINUE TO LOAD PROPPANT Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 24] REPORT DATE: [ 2/25/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 25] REPORT DATE: [ 2/26/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 62,281.39 Cumulative Cost (Cost) 4,021,666.34 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary CONTINUED FRAC RIGUP, ROLLED FRAC TANKS FOR TEMP REGULATION, STAGGED PROPPANT 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile MARTINEZ, DAVID Frac Supervisor 661-201-6437 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P DESTUFFING PROPPANT FROM CONTAINERS 06:00 19:00 13.00 RURD P RIGGED IN HHP AND BLENDER, DOUBLE TAPPED LINES, RIGGED IN ePRV TANK, CONTINUED PROPPANT PREP 19:00 23:59 4.99 RURD P CONTINUED STAGING PROPPANT Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 25] REPORT DATE: [ 2/26/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 26] REPORT DATE: [ 2/27/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 62,281.39 Cumulative Cost (Cost) 4,083,947.73 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary CONTINUED FRAC RIG UP,NIPPLED UP LAUNCH STACK, SET IA, OA TANKS, ROLLED FRAC TANKS THROUGH MANIFOLD, CONTINUED TO STAGE PROPPANT STAGED PROPPANT 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile MARTINEZ, DAVID Frac Supervisor 661-201-6437 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P CONTINUED RUNNING IRON PAST THE RIG TO SLOT 10, UNSTUFFED PROPPANT CONTAINERS, MONITORED WATER TANKS 06:00 08:00 2.00 RURD P CONTINUED RIG UP, SPOTTED FRAC SHACK, AND GREAT NORTH 08:00 12:00 4.00 RURD T LAUNCHER STACK WAS FROZEN AND UNOBPERABLE DUE TO ICE BLOCKAGE, LOCATED A HEATER TO THAW STACK, 12:00 18:00 6.00 RURD P FLEW IN, NIPPLED UP LAUNCHER STACK, RIGGED IN IA, OA LINES, CONTINUED TO RUN IRON, BEGAN THE INSTALLATION OF IRON RESTRAINTS 18:00 23:59 5.99 RURD P SPOTTED LAUNCH PUMP, TIED IN THE RISERS, CONTINUED PROPPANT MANAGEMENT Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 26] REPORT DATE: [ 2/27/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 27] REPORT DATE: [ 2/28/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 71,011.87 Cumulative Cost (Cost) 4,154,959.60 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary COMPLETED FRAC RIG UP, ALL PROPPANT STAGED, STARTED EQUIPMENT,BEGIN FUNCTION TESTING 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile MARTINEZ, DAVID Frac Supervisor 661-201-6437 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 RURD P CONTINUE HARD LINE RUN, INSTALL RESTRAINTS 06:00 18:00 12.00 RURD P COMPLETE HARD LINE, COMPLETE PROPPANT STAGING, INSTALL FUEL HEADS, FOUND FUEL TRUCK 11 WAS INOPERABLE, SWAPPED TRUCKS TO TRUCK 4, TROUBLE SHOOTING FUEL SYSTEM 18:00 00:00 6.00 RURD P COMPLETE RESTRAINT RIG IN. Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 27] REPORT DATE: [ 2/28/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 28] REPORT DATE: [ 3/1/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 814,427.14 Cumulative Cost (Cost) 4,969,386.74 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary PUMP STAGES 15-17, STAGE 15 PUMPED TO DESIGN, DART LANDED16 BBL EARLY, TOTAL PROPPANT PLACED 201,313 LB, TOTAL CLEAN VOLUME 2822 BBL, STAGE 16 PUMPED TO DESIGN, DART LANDED14 BBL EARLY, TOTAL PROPPANT PLACED 206,222 LB, TOTAL CLEAN VOLUME 1687 BBL, STAGE 17 PUMPED TO DESIGN, DART LANDED14 BBL EARLY, TOTAL PROPPANT PLACED 202,065 LB, TOTAL CLEAN VOLUME 1843 BBL, LRS PUT ON A 30 BBL FREEZE PROTECT 24hr Forecast General Remarks T/I/O INITIAL= 474/7/20 FINAL= 1138/700/509 ZX Code ZX02 Fracturing Contact Name Title Mobile MARTINEZ, DAVID Frac Supervisor 661-201-6437 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:30 6.50 RURD P LOADED LVT ON THE LAUNCH PUMP, COMPLETED RESTRAINTS, RECORDED TANK STRAPS AND TEMPS. CHECKED ALL PUMP FLUIDS, AND GREASERS. 06:30 07:30 1.00 RURD P SAFETY MEETING 07:30 09:00 1.50 RURD P PREPARED FOR FLOODING EQUIPMENT, FINAL WALKDOWN 09:00 09:40 0.68 RURD P FLOODED EQUIPMENT, STARTED PRIMING, LEAK ON THE LAUNCH LINE, AND TREATING LINE, REPAIRS MADE CONTINUED PRIMING.WHILE TRYING TO FAN OUT TO REPAIR AN IRON LEAK AN ICE BLOCKAGE WAS FOUND PREVENTING FLUID FLOW TO THE WELL. 09:40 11:58 2.30 RURD P BREAK IRON DOWN, ICE PLUG FOUND CLEAN OUT IRON, 11:58 12:51 0.88 RURD P ICE BLOCK CLEARED, RESUMING PRIME UP. 12:51 13:51 1.00 RURD P FUNCTION TESTING ePRV, PRESSURE TESTING, STARTING PSI 9504, 5 MINUTE PSI, 9374 GOOD TEST, LOADING DARTS MIXING GEL 13:51 14:44 0.88 PUMP P EQUALIZED TO 1000 PSI, OPENED WELL, 415 OPENING PSI, PERFORMED SWEEP, LAUNCHED DART @ 350 BBL JSV, LANDED 16 EARLY @549 BBL JSV,BH SEAT: 3601, BH PEAK: 6540, BH DIFF: 2939 PSI, PUMPED DFIT, SHUT IN FOR MONITORING. 14:44 15:14 0.50 PUMP P HELD DIAGNOSTIC PSI FOR 30 MINUTES, CLOSURE PSI 3328 PSI, A CHICKSAN HAD A WEEP HOLE LEAK, ON A PUMP, THE TIME WAS USED TO SWAP THE IRON 15:14 15:56 0.70 PUMP P PRIME PUMPS, PRESSURE TEST,PSI START 9464, PSI END 9215 15:56 16:38 0.70 PUMP P BRING ON CHEMS, EQUALIZED TO 1000 PSI OPENING PSI 754, PROCEEDED INTO STEP RATE TEST, ESTABLISHED GOOD XL, STAGED INTO PAD 16:38 17:08 0.50 PUMP T BLENDER LA MALFUNCTION LOST MO INJECTION, SLOWED RATE WENT TO FLUSH 17:08 18:08 1.00 PUMP P SWAPPED LA PUMPS, WENT TO LA 4 ON THE BLENDER, ESTABLISHED GOOD XL, RESTARTED PAD. STAGE PUMPED TO DESIGN, TOTAL 100 MESH 3000 LB, TOTAL 16/20 198,313 TOTAL SLURRY 3036, VOLUME, TOTAL CLEAN 2822, DART LAUNCHED @ 3607 JSV DISPLACEMENT VOLUME 207 BBL. 18:08 19:01 0.88 PUMP P DART LANDED @ 3750, 14 BBL EARLY BH SEAT: 3813, BH PEAK: 7495, BH DIFF: 3682 PSI STAGE PUMPED TO DESIGN, TOTAL 100 MESH 3000 LB, TOTAL 16/20 203,222 TOTAL SLURRY 1905, VOLUME, TOTAL CLEAN 1687, DART LAUNCHED @ 5520 JSV DISPLACEMENT VOLUME 199 BBL. 19:01 19:50 0.82 PUMP P DART LANDED @ 5654 JSV, 14 BBL EARLY, BH SEAT: 3683 PSI, BH PEAK 6720, BH DIFF: 3037, STAGE PUMPED TO DESIGN, TOTAL 100 MESH 3000 LB, TOTAL 16/20 199,065 TOTAL SLURRY 2058, VOLUME, TOTAL CLEAN 1843. 19:50 23:59 4.15 WAIT P RELOAD WATER AND PROPPANT, WORK ON CLEARING ICE IN THE BLEED LINE, Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 28] REPORT DATE: [ 3/1/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Stimulation Intervals Interval Number Start Date End Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Volume Clean Total (bbl) Volume Slurry Total (bbl) 15 3/1/2025 13:54 3/1/2025 18:06 0.0 0.0 203,000.0 201,313.0 3,424.10 3,637.92 16 3/1/2025 18:06 3/1/2025 19:00 0.0 0.0 203,000.0 205,155.0 1,687.38 1,905.28 17 3/1/2025 19:00 3/1/2025 19:51 0.0 0.0 203,000.0 202,363.0 1,933.12 2,148.09 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 29] REPORT DATE: [ 3/2/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 916,947.43 Cumulative Cost (Cost) 5,886,334.17 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary PUMP STAGES 18-20 STAGE 18 PUMPED TO DESIGN, DART LANDED10 BBL EARLY, TOTAL PROPPANT PLACED 203,435 LB, TOTAL CLEAN VOLUME 1893 BBL, STAGE 19 PUMPED TO DESIGN, DART LANDED14 BBL EARLY, TOTAL PROPPANT PLACED 204,035LB, TOTAL CLEAN VOLUME 1634 BBL, STAGE 20 NOT PUMPED TO DESIGN CUT SHORT DUE TO WATER LOSS, DART LANDED16 BBL EARLY, TOTAL PROPPANT PLACED 156,488 LB, TOTAL CLEAN VOLUME 1639 BBL, LRS PUT ON A 35 BBL FREEZE PROTECT 24hr Forecast General Remarks T/I/O INITIAL= 460/115/0 FINAL= 925/700/330 ZX Code ZX02 Fracturing Contact Name Title Mobile MARTINEZ, DAVID Frac Supervisor 661-201-6437 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 08:00 8.00 WAIT P LOADING, HEATING WATER, LOADING PROPPANT, THAWING HARDLINE 08:00 08:30 0.50 WAIT P SAFETY MEETING 08:30 11:30 3.00 WAIT T TOP SWAB FROZEN 11:30 11:54 0.40 WAIT P PRIMING EQUIPMENT 11:54 12:48 0.90 WAIT P TESTING EPRV FOUD THE BACK UP HEAD WAS NOT RESETTING, ETECH MADE REPAIRS FUNCTION TESTED 2 TIMES RESUMED WITH TESTING, PSI TESTING PSI START 9520, LEAK FOUND ON A WING, BAD HIGH PSI SEAL, BLED DOWN MADE REPAIRS RETEST STARTING PSI, 9550 ENDING PSI 9365, GOOD TEST 12:48 13:40 0.88 WAIT P LOAD DARTS,17, 18,19,20, DUMB DART, MIX GEL, LOAD CHEMS 13:40 14:52 1.20 PUMP P EQUALIZE TO 1000, OPENING PSI 460, BROUGHT RATE TO 15, LAUNCHED DART 17@ 28 BBL, LANDED @ 208 JSV 10 BBL EARLY, BH SEAT: 3639, BH PEAK: 6789, BH DIFF: 3150 PSI,INTERVAL PUMPED TO DESIGN, TOTAL 100 MESH 3000 LB, TOTAL 16/20 200,435 TOTAL SLURRY 2110, VOLUME, TOTAL CLEAN 1893, DART LAUNCHED @ 2118 JSV DISPLACEMENT VOLUME 182 BBL 14:52 15:40 0.80 PUMP P DART LANDED @ 2236, 14 BBL EARLY BH SEAT: 3637, BH PEAK: 6873, BH DIFF: 3236 PSI STAGE PUMPED TO DESIGN, TOTAL 100 MESH 3000 LB, TOTAL 16/20 201,035 TOTAL SLURRY 1851, VOLUME, TOTAL CLEAN 1634, DART LAUNCHED @ 3977 JSV DISPLACEMENT VOLUME 175 BBL. 15:40 16:30 0.83 PUMP P DART LANDED @ 4138, 16 BBL EARLY BH SEAT: 3508, BH PEAK: 6629, BH DIFF: 3121 PSI, STAGE CUT SHORT FOR LOSS OF WATER, TOTAL 100 MESH 3000 LB, TOTAL 16/20 153488 TOTAL SLURRY 1802, VOLUME, TOTAL CLEAN 1639, LRS PUMPED 35 BBL FREEZE PROTECT 16:30 18:00 1.50 WAIT P FAN OUT, BLOW DOWN, FREEZE PROTECT 18:00 23:59 5.98 WAIT P LOAD/ HEAT WATER, LOAD PROPPANT Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 29] REPORT DATE: [ 3/2/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Stimulation Intervals Interval Number Start Date End Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Volume Clean Total (bbl) Volume Slurry Total (bbl) 18 3/2/2025 13:39 3/2/2025 14:50 0.0 0.0 203,000.0 203,967.0 1,941.33 2,157.99 19 3/2/2025 14:50 3/2/2025 15:41 0.0 0.0 203,000.0 203,895.0 1,634.33 1,850.92 20 3/2/2025 15:41 3/2/2025 16:30 0.0 0.0 156,000.0 153,488.0 1,668.62 1,831.71 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 30] REPORT DATE: [ 3/3/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 509,550.32 Cumulative Cost (Cost) 6,395,884.49 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary PUMP STAGES 21&22 STAGE 21 PUMPED TO DESIGN, DART LANDED 14 BBL EARLY, TOTAL PROPPANT PLACED 202,630 LB, TOTAL CLEAN VOLUME 1805 BBL, STAGE 22 PUMPED TO DESIGN, DART LANDED 8 BBL EARLY, TOTAL PROPPANT PLACED 202,628LB, TOTAL CLEAN VOLUME 1811 BBL, 24hr Forecast General Remarks T/I/O INITIAL= 395/59/0 FINAL= 1172/700/106 ZX Code ZX02 Fracturing Contact Name Title Mobile MARTINEZ, DAVID Frac Supervisor 661-201-6437 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:30 6.50 WAIT P LOAD/HEAT WATER, LOAD PROPPANT, 06:30 07:00 0.50 WAIT P SAFETY MEETING 07:00 10:00 3.00 WOUR T SWAPPING STARTER ON THE BLENDER 10:00 11:06 1.10 WAIT P PULLING ON BRINE, PRIMING PUMPS PRESSURE TESTING, FOUND A LEAK ON A HIGH PSI SEAL, REPAIRES MADE RESUMED TEST, STARTING PSI 9480, ENDING 5 MINUTES 9242 PSI 11:06 11:36 0.50 WAIT P LOADING DARTS, MIXING GEL, PRIMING CHEMS 11:36 12:39 1.06 PUMP P EQUALIZINED TO 1000, OPENING PSI 392 PSI, ESTABLISHED INJECTION, LAUNCHED DART @ 23 JSV, LANDED @ 179 JSV 11 BBL EARLY,BH SEAT: 3264, BH PEAK: 6252, BH DIFF: 2988,j TOTAL 100 MESH 3000 LB, TOTAL 16/20 199,630 TOTAL SLURRY VOLUME2020, TOTAL CLEAN 1805, DART LAUNCHED @ 2031 JSV DISPLACEMENT VOLUME 160 BBL. 12:39 13:33 0.90 PUMP P DART LANDED @ 2183 8 BBL EARLY BH SEAT: 3449, BH PEAK: 6369, BH DIFF: 2920 STAGE PUMPED TO DESIGN, TOTAL 100 MESH 3000 LB, TOTAL 16/20 199,628 TOTAL SLURRY VOLUME 2043, TOTAL CLEAN 1811 13:33 18:00 4.45 DMOB P 15 MINUTE ISIP, FAN OUT BLOW DOWN, START RIGGING DOWN 18:00 23:59 5.98 DMOB P CONTINUE BREAKING DOWN HARDLINE, CONTINUE TO LOAD/HEAT WATER Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 30] REPORT DATE: [ 3/3/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Stimulation Intervals Interval Number Start Date End Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Volume Clean Total (bbl) Volume Slurry Total (bbl) 21 3/3/2025 11:32 3/3/2025 12:34 0.0 0.0 203,000.0 202,553.0 1,846.95 2,062.11 22 3/3/2025 12:34 3/3/2025 13:34 0.0 0.0 203,000.0 202,629.0 1,851.86 2,067.09 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 31] REPORT DATE: [ 3/4/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) 655,011.00 AFE / RFE / Maint.# GKA.00044.E.W003.CO.I S Network/Order Number 10458797 AFE+Supp Amt (Cost) 655,011.00 Daily Cost Total (Cost) 56,681.39 Cumulative Cost (Cost) 6,452,565.88 Weather Temperature (°F) Road Condition Poor Wind Last 24hr Summary RIG DOWN, DROPPED RISERS, BROKE DOWN TREATING IRON TO 3T-612, RAN OUT BLEED, PRV, AND TUBING HARD LINES. LOADING / HEATING WATER 24hr Forecast General Remarks ZX Code ZX02 Fracturing Contact Name Title Mobile MARTINEZ, DAVID Frac Supervisor 661-201-6437 LAWSON, JACOB Supervisor 971-606-0075 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 00:00 06:00 6.00 DMOB P CONTINUED THE RIG DOWN PROCESS, MOBILIZED CHEM FLATS TO PRUDHOE, CONTINUED HEATING/ LOADING WATER 06:00 14:00 8.00 DMOB P BROKE DOWN TREATING IRON TO 3T-612, DROPPED RISERS, REMOVED TREE HARDLINE. Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 120.0 SEAWATER 23,139.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment FAUR, DAN,Wells Supervisor 12/4/2024 06:00 12/4/2024 17:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/5/2024 06:00 12/5/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/6/2024 00:00 12/6/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/7/2024 00:00 12/7/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/8/2024 00:00 12/8/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/9/2024 00:00 12/9/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/10/2024 00:00 12/10/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/11/2024 00:00 12/11/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/12/2024 00:00 12/12/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/13/2024 00:00 12/13/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/14/2024 00:00 12/14/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/15/2024 00:00 12/15/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/16/2024 00:00 12/16/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/17/2024 00:00 12/17/2024 23:59 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/18/2024 00:00 12/18/2024 19:00 FRAC HES Frac Equipment FAUR, DAN,Wells Supervisor 12/19/2024 06:00 12/19/2024 19:00 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/18/2025 00:00 2/18/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/19/2025 00:00 2/19/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/20/2025 00:00 2/20/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/21/2025 00:00 2/21/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/22/2025 00:00 2/22/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/23/2025 00:00 2/23/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/24/2025 00:00 2/24/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/25/2025 00:00 2/25/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/26/2025 00:00 2/26/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/27/2025 00:00 2/27/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 2/28/2025 00:00 2/28/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/1/2025 00:00 3/1/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/2/2025 00:00 3/2/2025 23:59 FRAC HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/3/2025 00:00 3/3/2025 23:59 FRAC Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 31] REPORT DATE: [ 3/4/2025] Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES Frac Equipment BURKETT, CHAD,Wells Supervisor 3/4/2025 00:00 3/4/2025 23:59 FRAC Offline Activities Type Subtype Des Start Date End Date PUMPING 60 12/9/2024 06:00 12/15/2024 18:00 Page 1/1 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 1] REPORT DATE: [ 2/11/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) AFE / RFE / Maint.# Network/Order Number 10458798 AFE+Supp Amt (Cost) Daily Cost Total (Cost) Cumulative Cost (Cost) Weather Temperature (°F) Road Condition Wind Last 24hr Summary DRIFTED W/ 3.77" GAUGE RING TO DB-NIPPLE @ 9,883' RKB, DB-LOCK W/ P-BODY PLUG IN DB-NIPPLE @ 9,883' RKB, ATTEMPT TO SET BAITED PRONG IN PLUG (UNSUCCESSFUL), JOB IN PROGRESS 24hr Forecast General Remarks INITIAL T/I/O = 1350/1350/80 FINAL T/I/O = 600/1000/80 ZX Code ZX72 Secure / Unsecure Well Contact Name Title Mobile MCCLURE, BRANDON Slickline Operator 907-631-9077 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 05:30 08:00 2.50 TRAV P OBTAIN WELL FILE, MEET W/ CWG, DISCUSS JOB SCOPE, PICK UP EQUIPMENT ON 3G, TRAVEL TO 3T-608, NOTIFY DSO, CHECK IN W/ SITE CONTROL, INSPECT LOCATION, PJSM 08:00 10:00 2.00 RURD P R/U SLICKLINE .125" (carbon), RE-PACK/RE-TIE, STACK PCE, LOAD IN TOOLS, SWAB VALVE LEAKING, SLICK DIESEL IN UP-RIGHT GELLED UP, NOTIFY VALVE CREW, DIESEL TRANSPORT IN ROUTE 10:00 13:00 3.00 WOPT P STAND BY FOR VALVE CREW, AND TRANSPORT OF DIESEL, SWAB VALVE AND MASTER SERVICED, TANKER TRANSPORT ARRIVE ON LOCATION, P/T PCE W/ DIESEL TO 300L/3000H 13:00 15:00 2.00 SLKL P RIH W/ KJ, 3'x1-7/8" STEM, 3.77" GUAGE RING, BRING ON PUMP W/ DIESEL @ 1.5- BPM, SAT DOWN @ 7' SLM, WORKED GUAGE RING DOWN FREED UP @ 164' SLM, WORKED AREA UNTIL CLEAN, CONTINUED DRIFTING W/ NO ISSUES, LOCATED DB- NIPPLE (9,883' RKB) SAT DOWN @ 9,916' SLM, COME OFF THE PUMP @ 115-BBL, POOH.....OOH W/ GUAGE RING 15:00 17:30 2.50 SLKL P RIH W/ KJ, 4-1/2" Z-6 (4x brass carrier, 2x brass setting), DB-LOCK, P-BODY (4x 3/16" ports), 2' FILL EXT, END CAP (LIH=54"), BRING ON PUMP W/ DIESEL @ 1-BPM FOR 30 -BBL, LOCATED DB-NIPPLE (9,883' RKB), SAT DOWN @ 9,908' SLM, TAPPED DOWN, SEEN TRAVEL, BEAT DOWN FOR 30-MIN, GOOD 1000# OVER PULL, SHEERED OFF CLEAN, SEE 75# WEIGHT LOSS, POOH.....OOH W/ TATTLE TAIL SPRING IN UPPER GROVE (GOOD SET) 17:30 20:00 2.50 SLKL P RIH W/ 4-1/2" GS (1/4" brass), BAIT SUB, 1-7/8" PRONG (LIH=100"), LOCATED DB- PLUG (9,883' RKB) SAT DOWN @ 9,899' SLM, TAPPED DOWN, TESTED PLUG TO 2500-PSI, BEAT DOWN 45-MIN, UNABLE TO SHEAR OFF, POOH......OOH W/ BAITED PRONG, GS PIN UNTOUCHED 20:00 21:00 1.00 DMOB P LAY DOWN SLICKLINE, LRS R/D FROM P-SUB, INSTALL TREE CAP AND TEST, DOWN STACK PCE, INSPECT LOCATION, NOTIFY DSO 21:00 22:30 1.50 TRAV P TRAVEL TO F-WING, RETURN WELL FILE, SYNC DAILY WELL LOG Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 165.0 165.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES 772 POTTER, JASON,Wells Supervisor 2/11/2025 05:30 2/11/2025 22:00 SLICK LINE HES 772 POTTER, JASON,Wells Supervisor 2/12/2025 05:30 2/12/2025 23:59 SLICK LINE Offline Activities Type Subtype Des Start Date End Date PUMPING 74-H 2/11/2025 07:30 2/12/2025 22:15 Page 1/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 2] REPORT DATE: [ 2/12/2025] API / UWI 5010320890 Original KB/RT Elevation (ft) 51.00 Ground Elevation (ft) 12.00 Original Spud Date 10/14/2024 Primary Job Type INITIAL COMPLETION Secondary Job Type STIMULATION Total AFE (Cost) AFE / RFE / Maint.# Network/Order Number 10458798 AFE+Supp Amt (Cost) Daily Cost Total (Cost) Cumulative Cost (Cost) Weather Temperature (°F) Road Condition Wind Last 24hr Summary SET PRONG IN DB P-BODY @ 9,883' RKB, TESTED TO 2500-PSI, PULLED OV IN ST#1 @ 2,114' RKB, CIRC OUT W/ 100-BBL OF DIESEL, SET INCONEL BTM. LATCH DUMMY IN ST#1, PERFORMED MIT-T TO 4,550-PSI (PASSED), PULLED PRONG AND DB P-BODY FROM DB-NIPPLE @ 9,883' RKB, READY FOR FRAC. 24hr Forecast General Remarks INITIAL T/I/O = 600/1050/80 FINAL T/I/O = 300/0/80 ZX Code ZX72 Secure / Unsecure Well Contact Name Title Mobile MCCLURE, BRANDON Slickline Operator 907-631-9077 Time Log Start Time End Time Dur (hr) Phase Activity Code Time P- T-X Operation 05:30 07:00 1.50 TRAV P OBTAIN WELL FILE, MEET W/ CWG, DISCUSS JOB SCOPE, PICK UP TOOLS @ WLB, TRAVEL TO 3T-608, NOTIFY DSO, INSPECT LOCATION, PJSM 07:00 08:00 1.00 RURD P PICK UP SLICKLINE .125" (carbon), STACK PCE, CHANGE OUT T/S, LRS R/U TO TREE, P/T PCE W/ DIESEL TO 300L/3000H ***5'x2-5/8" ROLLER,KJ,5'x2- 5/8"ROLLER,OJ,KJ,LSS*** ***START TIME-08:00*** 08:00 09:30 1.50 WOPT P LRS ARRIVE ON LOCATION, PUMP TRUCKING SPOTTED UP, R/U TO P-SUB, P/T PCE W/ DIESEL TO 300L/3000H 09:30 12:00 2.50 SLKL P RIH W/ KJ, 4-1/2" GS (3/16" brass), BAIT SUB, 1-7/8" PRONG (LIH=100"), LOCATED DB- PLUG (9,883' RKB) SAD DOWN @ 9,901' SLM, TAPPED DOWN SEEN TRAVEL, TESTED PLUG TO 2500-PSI, BEAT DOWN 20-MIN TO SHEAR OFF, TUBING STILL HOLDING, BLEED TUBING DOWN TO 900-PSI, POOH.....OOH W/ SHEARED GS 12:00 13:15 1.25 SLKL P RIH W/ KJ, 4-1/2" OK-1, 1-1/4" JDC, LOCATED ST#1 (2,114' RKB), SAT DOWN @ 2,099' SLM, 2x LITE OJ COMES FREE, POOH.....OOH W/ NO VALVE 13:15 14:30 1.25 SLKL P RIH W/ KJ, 4-1/2" OK-1, 1-1/4" JDC, LOCATED ST#1 (2,114' RKB), SAT DOWN LATCHED UP @ 2,097' SLM, 1x LITE OJ COMES FREE, LOCATED SAT BACK DOWN, TAPPED DOWN 3 TIMES, COME OFF W/ 2x HEAVY OJ LICKS, SEE TUBING FALL OFF, POOH.....OOH W/ ORFICE VALVE 14:30 16:45 2.25 SLKL P STAB BACK ON WELL, P/T PCE, CLOSE SWAB, LRS R/U TO WING & LINES UP FOR TUBING TO IA CIRC OUT, CIRCED 100-BBL DIESEL @ 1-BPM 16:45 18:45 2.00 SLKL P RIH W/ KJ, 4-1/2" OK-1, JK, INCONEL BTM. INT. LATCH, 1" DUMMY W/ CALLETS, LOCATED ST#1 (2,114' RKB) SAT DOWN @ 2,096' SLM, TAPPED DOWN SEEN TRAVEL, GOOD 600# OVER PULL, SHEARED OFF CLEAN, POOH.....OOH W/ INDICATIONS OF GOOD SET, COME OFF WELL, INSTALL TREE CAP AND TEST, BLEED IA TO 0-PSI, PERFORM MIT-T TO 4,550-PSI, INITIAL=300/0/80, TEST (4.3-BBL) =4550/475/80, 15-MIN=4350/475/80, 30-MIN=4250/475/80 (PASS) 18:45 20:15 1.50 SLKL P RIH W/ KJ, 4-1/2" GR, LOCATED BAITED PRONG (9,873' RKB) SAT DOWN LATCHED UP @ 9,901' SLM, 3x OJ LICKS COMES FREE, SEE EQUALIZATION, POOH.....OOH W/ BAITED PRONG 20:15 21:45 1.50 SLKL P RIH W/ KJ, 4-1/2" PRS, LOCATED DB-PLUG BODY (9,883' RKB) SAT DOWN LATCHED UP @ 9,907' SLM, 5x HEAVY OJ LICKS COMES FREE, PULLED HEAVY TO SURFACE.....OOH W/ DB-PLUG BODY 21:45 22:30 0.75 DMOB P R/D SLICKLINE, LRS R/D FROM WING, INSTALL TREE CAP AND TEST, DOWN STACK PCE, INSPECT LOCATION, NOTIFY DSO ***END TIME-22:00*** 22:30 23:59 1.49 DMOB P TRAVEL EQUIPMENT TO HEAVY LINE, TRAVEL TO F-WING, RETURN WELL FILE, SYNC DAILY WELL LOG Report Fluids Summary Fluid To well (bbl) Cum to Well (bbl) DIESEL 100.0 265.0 Contractor Rig Name/# Rig Supervisor Rig Accept Date RR Date Rig Type HES 772 POTTER, JASON,Wells Supervisor 2/11/2025 05:30 2/11/2025 22:00 SLICK LINE HES 772 POTTER, JASON,Wells Supervisor 2/12/2025 05:30 2/12/2025 23:59 SLICK LINE Page 2/2 3T-608 Report Printed: 3/12/2025 Daily STIM Report ORIG SPUD DATE: [ 10/14/2024 ] DRLG RIG RELEASE: [ 11/20/2024 ] ON PRODUCTION: [ ] REPORT # [ 2] REPORT DATE: [ 2/12/2025] Offline Activities Type Subtype Des Start Date End Date PUMPING 74-H 2/11/2025 07:30 2/12/2025 22:15 Transmittal #1417 Detail Date: 2/3/2025 To (External Party): From (CPAI Contact): Email*: aogcc.data@alaska.gov Email*: richard.e.elgarico@conocophillips.com First Name*: Meredith First Name*: Ricky Last Name*: Guhl Last Name*: Elgarico Phone Number:Phone Number: 907 265-6580 Company: AOGCC Company: ConocoPhillips Address: 333 W. 7th Ave., Suite 1000 Address: 700 G Street City: Anchorage City: Anchorage State: AK State: AK Zip Code: 99501 Zip Code: 99501 Transmittal Info Sent Via: ShareFile Tracking #: Justification: Data Detail Quantity*: Description*: Type*: 1 3T-608 LWD, Survey, TOC Well Logs Attachments: Received By: ___________________________ Signature: ___________________________ Date: _________________ Approver: ___________________________ Signature: ___________________________ Date: _________________ 224-094 T40045 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.03 13:55:11 -09'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-12-04_22629_KRU_3T-608_MemoryRadialCementBondLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22629 KRU 3T-608 50-103-20890-00 Memory Radial Cement Bond Log 04-Dec-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 224-094 T39898 12/30/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.30 12:42:01 -09'00' t >>ED W/η^ Zs/ KZ Zη &/ >ED ^ Zs/ ^Z/Wd/KE >/s Z> ^Z/Wd/KE ddzW d >K'' K>KZWZ/Ed^ ͲĞůŝǀĞƌLJ3T-608 50-103-20890-00-00 224-094 KUPARUK RIVER MWD/LWD/DD VISION Service FINAL FIELD 26-Nov-24 1GMTU MT7-88 50-103-20893-00-00 224-111EATER MOOSES TOOMEMORY Top of Cement PROCESSED 29-Nov-24 1dƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺ yͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺWƌŝŶƚEĂŵĞ ^ŝŐŶĂƚƵƌĞ ĂƚĞWůĞĂƐĞƌĞƚƵƌŶǀŝĂĐŽƵƌŝĞƌŽƌƐŝŐŶͬƐĐĂŶĂŶĚĞŵĂŝůĂĐŽƉLJƚŽ^ĐŚůƵŵďĞƌŐĞƌ͘ďŚĂƚƚĂĐŚĂƌLJĂΛƐůď͘ĐŽŵ^>ƵĚŝƚŽƌͲdƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚƐŝŐŶĂƚƵƌĞĐŽŶĨŝƌŵƐƚŚĂƚĂƉĂĐŬĂŐĞ;ďŽdž͕ĞŶǀĞůŽƉĞ͕ĞƚĐ͘ͿŚĂƐďĞĞŶƌĞĐĞŝǀĞĚĂŶĚƚŚĞĐŽŶƚĞŶƚƐŽĨƚŚĞƉĂĐŬĂŐĞŚĂǀĞďĞĞŶǀĞƌŝĨŝĞĚƚŽŵĂƚĐŚƚŚĞŵĞĚŝĂŶŽƚĞĚĂďŽǀĞ͘dŚĞƐƉĞĐŝĨŝĐĐŽŶƚĞŶƚŽĨƚŚĞƐĂŶĚͬŽƌŚĂƌĚĐŽƉLJƉƌŝŶƚƐŵĂLJŽƌŵĂLJŶŽƚŚĂǀĞďĞĞŶǀĞƌŝĨŝĞĚĨŽƌĐŽƌƌĞĐƚŶĞƐƐŽƌƋƵĂůŝƚLJůĞǀĞůĂƚƚŚŝƐƉŽŝŶƚ͘η^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ224-094: T39841224-111: T39842Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.12.09 14:28:13 -09'00'224-094: T39841224 111 T398423T-60850-103-20890-00-00224-094KUPARUK RIVERMWD/LWD/DDVISION ServiceFINAL FIELD26-Nov-241 CAUTION: This email originated from outside the State of Alaska mail system. Do not From:Hobbs, Greg S To:Loepp, Victoria T (OGC); AOGCC Permitting (CED sponsored); Wallace, Chris D (OGC); Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Roby, David S (OGC) Cc:AOGCC Records (CED sponsored) Subject:RE: [EXTERNAL]APPROVAL PTD 224-094 Sundry 324-661 Pump Rate Change Frac Date:Monday, December 2, 2024 2:23:40 PM Attachments:image001.png Thank-you Victoria- Greg From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, December 2, 2024 1:09 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: [EXTERNAL]APPROVAL PTD 224-094 Sundry 324-661 Pump Rate Change Frac Greg, Approval is granted for the pump rate change outlined below. Please include a copy of this approval with your copy of the approved sundry. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Nozaki, Manabu <Manabu.Nozaki@conocophillips.com> Sent: Monday, December 2, 2024 12:06 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Glasheen, Kirsty <Kirsty.Glasheen@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Metzgar, Kyle N <Kyle.N.Metzgar@conocophillips.com>; Nozaki, Manabu <Manabu.Nozaki@conocophillips.com> Subject: RE: [EXTERNAL]Completed Sundry 324-661 click links or open attachments unless you recognize the sender and know the content is safe. Hi, Regarding the approved 3T-608 frac sundry, we would like to increase the pump rate from 30 bpm to37 bpm. This will not affect the pressures in the table below. If we see high friction pressure, we willdecrease the pump rate accordingly. Is there any issue with the pump rate change? Regards,Manabu From: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Sent: Wednesday, November 27, 2024 8:23 AM To: Glasheen, Kirsty <Kirsty.Glasheen@conocophillips.com>; Nozaki, Manabu <Manabu.Nozaki@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: FW: [EXTERNAL]Completed Sundry 324-661 From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov> Sent: Wednesday, November 27, 2024 7:57 AM To: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: [EXTERNAL]Completed Sundry 324-661 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello, Attached is the completed Sundry for KRU 3T-608. Happy Thanksgiving, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska, and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use, or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Kuparuk River Field, Torok Oil Pool, KRU 3T-608 Conoco Phillips Alaska, Inc. Permit to Drill Number: 224-094 Revised Surface Location: 1943' FSL, 596' FWL, SENE S1 T12N R7E Bottomhole Location: 4372' FSL, 181' FWL, SENW S23 T13N R7E 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 AOGCCreserves 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 AOGCCspecifically 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 AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie /Chmielowski Commissioner DATED this 30th day of September 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.30 20:10:37 -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: 21191.32 TVD:5056 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 10/10/2024 Total Depth:9. Acres in Property:14. Distance to Nearest Property: 908' to ADL355036 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 51.1 15. Distance to Nearest Well Open Surface: x-467806 y- 6003669 Zone- 4 12 to Same Pool: 772' to 3S-617 16. Deviated wells: Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 20" 94 H-40 Welded 80.9 39.1 39.1 120 120 13.5" 10.75" 45.5 L80 Hyd563 2648.28 39.1 39.1 2687.38 2514 9.875" 7.625" 29.7 L80 Hyd563 9198.59 39.1 39.1 9237.69 4842 9.875" 7.625" 33.7 P110-S Hyd563 800 9237.69 4841.8 10037.69 5030 6.5" 4.5" 12.6 P110-S Hyd563 11303.63 9887.69 5001.35 21191.32 5056 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: Brian Broussard Chris Brillon Contact Email:Brian.T.Broussard@cop.com Wells Engineering Manager Contact Phone:907-263-4090 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10 yds P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field Torok Oil Pool 1943' FSL, 596' FWL, SENE S1 T12N R7E ADL025528 / ADL393883 (including stage data) 4191' FSL, 2881' FWL, NWSE S35 T13N R7E LONS 01-013 4372' FSL, 181' FWL, SENW S23 T13N R7E 2560 / 5760 GL / BF Elevation above MSL (ft): 2316 1798 18. Casing Program: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips Alaska Inc. 59-52-180 KRU 3T-608 730sks 10.7ppg, 280sks 15.8ppg 700sks 14ppg, 138sks 15.3ppg Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks 1231sks 15.3ppg Casing Length Size Cement Volume MD Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Surface Conductor/Structural Liner Production Intermediate Perforation Depth MD (ft): Perforation Depth TVD (ft): 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: Commission Use Only See cover letter for other requirements. Stratigraphic Test No Mud log req'd: Yes No No Directional svy req'd: Yes No Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Single Well Gas Hydrates No Inclination-only svy req'd: Yes No Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal No No Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Grace Christianson at 10:42 am, Sep 05, 2024 DSR-9/26/24 2:25 pm, Sep 26, 2024 50-103-20890-00-00224-094 Initial BOP test to 5000 psig; subsequent BOP test to 4000 psig Annular preventer test to 2500 psig BOPE testing on a 21-day interval is approved with the attached conditions 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 A.Dewhurst 27SEP24VTL 9/26/2024 92 X ($8 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.30 20:10:55 -08'00' 08/13/24 09/30/24 RBDMS JSB 100224 <ZhϯdͲϲϬϴ 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. .58'67 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. 1 Christianson, Grace K (OGC) From:Broussard, Brian T <Brian.T.Broussard@conocophillips.com> Sent:Wednesday, September 4, 2024 4:54 PM To:AOGCC Permitting (CED sponsored) Cc:Hobbs, Greg S; Taylor, Jenna; Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Lee, David L; Brillon, Chris L; Loepp, Victoria T (OGC) Subject:Updated Permit to Drill Submission for 3T-608 (PTD: 224-094, API: 50-103-20890-00-00) Attachments:3T-608_Permit_224-094_Resubmission_SIGNED.pdf Follow Up Flag:Follow up Flag Status:Flagged Hello, Attached is an updated PTD application for the 3T-608 (PTD: 224-094, API: 50-103-20890-00-00). I was advised by Victoria to resubmit the full PTD application for the 3T-608 due to changes we have made to the well design. I have highlighted in red the changes to the well in the 10-401 document. Below is a summary of the changes: x Changed surface lead cement excess from 300% to 200%. x Changed 7-5/8” Intermediate Casing set point from top setting the Moraine formation to setting 5’ TVD below the Moraine formation top x Updated well plan which has minor changes due to the new intermediate casing set point. x Changed intermediate cement job from a single 15.3 ppg design to a 14 ppg lead/15.3 ppg tail design. x Change liner from uncemented to cemented. Added cement information for liner cement job. Thanks, Brian Broussard Drilling Engineer – Kuparuk 700 G Street, Anchorage, AK 99501 Cell: 337.967.0516 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 4, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill 3T-608 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Moraine Injector well from the 3T drilling pad. The intended spud date for this well is 10/10/2024. It is intended that Doyon 142 be used to drill the well. 3T-608 will utilize a 13 1/2” surface hole drilled to TD and 10 3/4” casing will be set and cemented to surface. As noted in section 4 of the attached proposed drilling program, the low maximum anticipated surface pressure of the well allows use of a three preventer BOPE per 20 AAC 25.035 (e) (1) (A) (i-iii). The fourth preventer will contain solid body pipe rams that will be sized for the intermediate casing string. The 9 7/8” intermediate hole will be drilled and set in the Moraine reservoir. A 7 5/8” casing string will be set and cemented from TD to secure the shoe and cover 250’TVD above any hydrocarbon-bearing zones (Coyote). The production interval will be comprised of a 6 1/2” horizontal hole that will be landed and geo-steered in the Moraine formation. The well will be completed as a cemented, fracture stimulated Injector with 4 1/2” liner, and frac sleeves. The upper completion will include a production packer with GLM’s and a downhole guage tied back to surface. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Brian Broussard at 907-263-4090 (Brian.T.Broussard@conocophillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: 3T-608 Well File / Jenna Taylor ATO 1560 David Lee ATO 1552 Brian Broussard Chris Brillon ATO 1548 Drilling Engineer Roland Kirschner ATO 636 Brian Broussard I am the author of this document 2024.09.04 16:39:59-08'00' Brian Broussard Application for Permit to Drill, 3T-608 Saved: 4-Sep-24 3T-608 PTD Page 1 of 9 Printed: 4-Sep-24 3T-608 Application for Permit to Drill Document Table of Contents 1.Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................................................................ 2 2.Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................................................................... 2 3.Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) ........................................................................ 1 4.Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3)) ............................................................. 1 5.Diverter System (Requirements of 20 AAC 25.005(c)(7)) ..................................................................................... 2 6.MASP Calculations (Requirements of 20 AAC 25.005(c)(4)) ................................................................................ 3 7.Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) ............................ 4 8.Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) ........................................................... 4 9.Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................................................................. 5 10.Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ........................................ 6 11.Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ................................................................................... 6 12.Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ................................................................... 6 13.Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ............................................................................. 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) ......... 6 15.Drilling Hazards Summary ................................................................................................................................. 6 16.Proposed Completion Schematic ....................................................................................................................... 8 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as 3T-608 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 1,943 FSL, 596 FWL, SENE S1 T12N R7E, UM NAD 1927 Northings: 6003669 Eastings:467806 RKB Elevation 51.1’AMSL Pad Elevation 12’AMSL Top of Productive Horizon (Heel) 4191‘ FSL, 2881‘ FWL, NWSE S35 T13N R7E, UM NAD 1927 Northings: 6011193 Eastings: 468535 Measured Depth, RKB: 10,038 Total Vertical Depth, RKB: 5,030 Total Vertical Depth, SS: 4,979 Total Depth (Toe) 4372‘ FSL, 181‘ FWL, SENW S23 T13N R7E, UM NAD 1927 Northings: 6021946 Eastings: 465871 Measured Depth, RKB: 21,191 Total Vertical Depth, RKB: 5,056 Total Vertical Depth, SS: 5,005 Pad Layout Attachment 1 – 3T-608 Area of Review (AOR) An Area of Review plot is show below of the 3T-608 injector planned wellpath and offset wells. 3S-617, 3S-610, NDST-02, NDST-02PB1, Colville Delta 2, and ODST-47 are the offset wells from the planned 3T- 608. injector. PTD API Well Name Status Top of Zone-of-Interest Isolating Stage TOC Method TOC Determination Losses (volume, % no reported) Returns verified Zonal Isolation Comments 223-085 5010320864 3S-617 Producing 8,432’ MD 7-5/8” Intermediate Cement 3,841’ MD Ultrasonic CBL None Yes Yes Will continue producing during 3T-608 execution 223-126 501032087500 3S-610 Producing 9,171’ MD 7-5/8” Intermediate Cement 3,549’ MD Ultrasonic CBL None Yes Yes Will continue producing during 3T-608 execution 212-163 501032066000 NDST-02 Suspended 9,907’ MD Intermediate RBP at 2,000’ MD. 8,907’ MD Pressure Test RBP to 2,500 psi for 30 min None No No Scheduled for lateral abandonment in August 2024, and final P&A in Q1 2024. 212-163 501032066070 NDST-02PB1 P&A’d 8,650’ MD Open Hole Cement Plug 6,287’ MD Physical Tag None, full returns Yes Yes Pilot Hole. Abandonment plug and kickoff plug set 85-0210 501032004700 Colville Delta 2 P&A’d 6,233’ MD Surface and Intermediate Cement Plug/Squeeze. Surface Visual/Cement Retainers None, full returns Yes Yes Exploration well P&A’d in 1986. 9-5/8” cut and welded with plate 212-103 507032066000 ODST-47 Suspended 12,723’ MD 4-1/2” liner TA plug 12,223’ MD Pressure test to 3,000 psi None. Squeezed 191 bbl cement in lateral No. 9 bbl balanced cement plug Yes Will create geological separation by drilling into the upper Moraine. (ODST-47 is in lower Moraine) Application for Permit to Drill, 3T-608 Saved: 4-Sep-24 3T-608 PTD Page 1 of 9 Printed: 4-Sep-24 3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 142 onto 3T-608 2. Rig up and test diverter and riser, dewater cellar as needed. 3. Drill 13 1/2” hole to the surface casing point as per the directional plan. 4. Run and cement 10 3/4” surface casing to surface. 5. Install BOPE and MPD equipment. 6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr regulatory notice). 7. Pick up and run in hole with 9 7/8” drilling BHA to drill the intermediate hole section. 8. Chart casing pressure test to 3,000 psi for 30 minutes. 9. Drill out 20’ of new hole and perform LOT. Maximum LOT to 18.0 ppg. Minimum LOT required to drill ahead is 11.0 ppg EMW. 10. Drill 9 7/8” hole to section TD, setting pipe above the Moraine Reservoir. (LWD Program: GR/RES). 11. Run 7 5/8” casing and cement to a minimum of 250’ TVD above any hydrocarbon bearing zones (cementing schematic attached). Pressure test casing if possible on plug bump to 4000 psi. 12. Test BOPE to 250 psi low / 4,000 psi high (24-48 Regulatory notice). 13. Pick up and run in hole with 6 1/2” drilling BHA. Log top of cement with sonic tool in recorded mode. 14. Chart casing pressure test to 4,000 psi for 30 minutes if not tested on plug bump. 15. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 14.5 ppg. Minimum required leak- off value is 11.0 ppg EMW. 16. Drill 6 1/2” hole to section TD (LWD Program: GR/RES/Den/Neu/Sonic). 17. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC. 18. Run 4 1/2” liner with toe valve, frac sleeves and liner hanger to TD. Cement liner in place to liner top. 19. Run 4 1/2” upper completion with glass plug, production packer, chemical injection mandrel with cap string, downhole gauge, and gas lift mandrels. Space out and land tubing hanger with pre-installed and pre-tested BPV. 20. Pressure test hanger seals to 3,850 psi. 21. Pressure test against the glass plug to set production packer, test tubing to 3,850 psi, chart test. 22. Bleed tubing pressure to 2200 psi and test IA to 3,850 psi, chart test. 23. Install HP-BPV and test to 2500 psi. 24. Nipple down BOP. 25. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes. 26. Freeze protect down tubing and annulus. 27. Secure well. Rig down and move out. Please note – This well will be frac’d 4. Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Doyon 142. Doyon 142 will use a BOPE stack equipped with an annular preventer, fixed 7 5/8” solid body rams, blind/shear rams and variable rams while drilling and running casing in the intermediate section of 3T-608. 3T-608 has a MASP of 1,755 psi in the intermediate hole section using the methodology in section 6 MASP calculations. With a MASP less than 3000 psi ConocoPhillips classifies the operation as a Class 2. Per 20AAC 25.035.e.a.A: For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including: i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except that pipe rams need not be sixed to bottom-hole assemblies and drill collars. ii. One with blind rams iii. One annular type Intermediate Drilling/Casing Production Proposed Configuration: Proposed Configuration: Annular Preventer (iii) Annular Preventer 7 5/8” fixed rams during drilling Intermediate VBRs in Upper Cavity Blind/Shear Rams (ii) Blind/Shear Rams VBRs (i) VBRs in Lower Cavity 5. Diverter System (Requirements of 20 AAC 25.005(c)(7)) A diverter will be utilized as there are no offset wells with surface shoes within 500’ of 3T-608. However, no hydrates are anticipated, and 3T-621 was recently drilled with no indications of hydrates occurring. Below is a schematic showing the planned location and 75’ exclusion zone of the diverter. 6. MASP Calculations (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD(ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) 20 119.1 / 119.1 10.9 53 56 10 3/4 2,687 / 2,514 13.5 1,124 1,513 7 5/8 10038 / 5,030 13.5 2,249 1,755 4 1/2 21,191 / 5,056 13.0 2,261 1,798 PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20” conductor ASP = [(FG x 0.052) – 0.1] D = [(10.9 x 0.052) – 0.1] x 119.1 = 56 psi OR ASP = FPP – (0.1 x D) = 1,124 – (0.1 x 2,514 ) = 873 psi 2. Drilling below 10.75” surface casing ASP = [(FG x 0.052) – 0.1] D = [(13.5 x 0.052) – 0.1] x 2,514 = 1,513 psi OR ASP = FPP – (0.1 x D) = 2,249 – (0.1 x 5,030 ) = 1,746 psi 3. Drilling below 7.625” intermediate casing ASP = [(FG x 0.052) – 0.1] D = [(13.0 x 0.052) – 0.1] x 5,030 = 3,028 psi OR ASP = FPP – (0.1 x D) = 2,261 – (0.1 x 5,056 )= 1,755 psi (B) data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 7. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out the casing shoe and perform LOT/FIT as per the procedure that ConocoPhillips Alaska has on file with the Commission. 8. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 20 42 94 H40 Welded Cemented to surface with 10 yds slurry 10 3/4 13 1/2 45.50 L80 Hyd563 Cement to Surface 7 5/8 9 7/8 29.70 33.70 L80 P110-S Hyd563 250’ TVD or 500’ MD, whichever is greater, above upper most producing zone (Coyote) 4 1/2 6 1/2 12.60 P110-S Hyd563 Cemented liner with frac sleeves Cementing Calculations 10 3/4” Surface Casing run to 2,687 ’ MD / 2,514 ’ TVD Cement 2,687 MD to 2,187 (500’ of tail) with Class G + Add's@ 15.8 PPG, and from 2,187' to surface with 10.7 ppg Arctic Lite Crete. Assume 200% excess annular volume in permafrost and 50% excess below the permafrost (1,693 ’ MD), zero excess in 20” conductor. Lead slurry from 2,187’ MD to surface with Arctic Lite Crete @ 10.7 ppg Total Volume = 2,117ft3 => 730 sx of 10.7 ppg Class G + Add's @ 2.92 ft3 /sk Tail slurry from 2,687 MD to 2,187’ MD with 15.8 ppg Class G + Add's Total Volume = 316 ft3 => 280 sx of 15.8ppg Class G + Add's @ 1.16 ft3/sk 7 5/8” Intermediate Casing run to 10038’ MD / 5,030 ’ TVD Top of slurry is designed to be at 5,866 ’ MD, which is 250’ TVD above the prognosis shallowest hydrocarbon bearing zone, Coyote. If a shallower hydrocarbon zone of producible volumes, is encountered while drilling, a 2-stage cement job will be performed to isolate this zone. Assume 40% excess annular volume. Lead slurry from 10,038’ MD to 9,538’ MD with 14 ppg Class G + Add’s Total Volume = 1,105 ft3 => 700 sx of 14 ppg Class G + Add’s @ 1.58 ft3/sk Tail slurry from 9,538’ MD to 5,866’ MD with 15.3 ppg Class G + Add's Total Volume = 171 ft3 => 138 sx of 15.3 ppg Class G + Add's @ 1.2455 ft3/sk 4 ½” Production Liner run to 21,191’ MD / 5,056’ TVD Cement production liner from 21,191’ MD to the liner top at 9,888’ MD with 15.3 ppg Class G + Add’s. The liner top will be set a minimum of 150’ inside the intermediate casing. Assume 10% excess annular hole volume and 0% excess cased hole volume. Slurry from 21,191’ MD to 9,888’ MD with 15.3 ppg Class G + Add’s Total Volume = 1,526 ft3 => 1231 sx of 15.3 ppg Class G + Add’s @ 1.24 ft3/sk 9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate Production Hole Size in. 13 1/2 9 7/8 6 1/2 Casing Size in. 10 3/4 7 5/8 4 1/2 Density PPG 8.6 – 9.8 9.0 – 9.6 9.0 – 9.5 PV cP 20-50 8-15 7-12 YP lb./100 ft2 30 - 80 20 - 30 15 - 30 Funnel Viscosity s/qt. 250 – 300 40-60 35-50 Initial Gels lb./100 ft2 30 - 50 8 - 15 5- 10 10 Minute Gels lb./100 ft2 50 - 70 <20 7 - 15 API Fluid Loss cc/30 min. N.C. – 15.0 < 10.0 < 6.0 HPHT Fluid Loss cc/30 min. N/A < 10.0 < 10.0 pH 9.5 – 10.0 9.5 – 10.0 9.5 – 10.5 Surface Hole: A water based spud mud will be used for the surface interval. Mud engineer to perform regular mud checks to maintain proper specifications The mud weight will be maintained at 9.8 ppg by use of solids control system and dilutions where necessary. Intermediate: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight at or below 9.6 ppg for formation stability and be prepared to add loss circulation material if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important. The mud will be weighted up to 9.5 ppg before pulling out of the hole. Production Hole: The horizontal production interval will be drilled with an inhibited fresh water polymer mud system weighted to 9.0 – 9.5 ppg. MPD will be available for adding backpressure during connections if necessary. Diagram of Doyon 142 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Drilling Hazards Summary 13 1/2" Hole / 10 3/4” Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Follow real time surveys very closely, gyro survey as needed to ensure survey accuracy. Gas Hydrates Low If observed – control drill, reduce pump rates and circulating time, reduce mud temperatures Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Running sands and gravels Low Maintain planned mud properties, increase mud weight, use weighted sweeps 9 7/8” Hole /7 5/8” Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale / Tight hole / Stuck Pipe Low Good hole cleaning, pre-treatment with LCM, stabilized BHA, maintain planned mud weights and adjust as needed, real time equivalent circulating density (ECD) monitoring Lost circulation Moderate Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Pressure (Coyote / K3) Low Well control drills, check for flow during connections, increase mud weight if necessary 6 1/2” Hole / 4 1/2” Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Moderate Reduce pump rates, real time ECD monitoring, maintain mud rheology, add lost circulation material Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Moderate Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Running Liner to Bottom Moderate Properly clean hole on the trip out with BHA, perform clean out run if necessary, utilize super sliders for weight transfer if needed, monitor T&D real time Well Proximity Risks: 3T is a multi-well pad, with only a few existing wells. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Unlikely to encounter any abnormal pressure, however, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. The overburden logs will be evaluated to ensure no hydrocarbon bearing zones are above the known Coyote. If identified, the primary intermediate cement job will be replanned to cover the zone as per the agency regulations. Lost Circulation: Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. 16. Proposed Completion Schematic 39 500 500 700 700 900 900 1300 1300 1600 1600 2000 2000 3000 3000 5000 5000 8000 8000 13000 13000 18000 18000 21192 3T-608 wp13.1 Plan Summary 0 4 Dogleg Severity0 3500 7000 10500 14000 17500 21000 Measured Depth 10-3/4" Surface Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 30.0 30.0 60.0 60.0 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in] 39100200300400500 3T-605 wp05 v5 39100200300400500601701802902 1002 3T-606 wp06 v5 39100200300400500601701 802 902 1003 1105 1206 1308 140915111613 3T-607 wp05 v5 391002003004005006007008008999991099119912991399 149915991699 17991899199920992199 3T-609 wp06 v5 39100200300400500600699 79989999910991199 3T-610 wp05 v5 39100200300400500600 3T-611 wp06 v5 0 3000 True Vertical Depth0 2750 5500 8250 11000 13750 16500 Vertical Section at 345.00° 10-3/4" Surface Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 15 30 Centre to Centre Separation0 425 850 1275 1700 2125 2550 2975 Measured Depth DDI 7.165 SURVEY PROGRAM Date: 2024-03-21T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.10 300.00 3T-608 wp13.1 (3T-608) INC 300.00 2680.00 3T-608 wp13.1 (3T-608) MWD+IFR2+SAG+MS 2680.00 10030.00 3T-608 wp13.1 (3T-608) MWD+IFR2+SAG+MS 10030.00 21191.32 3T-608 wp13.1 (3T-608) MWD+IFR2+SAG+MS Surface Location North / 6003419.54 East / 1607838.06 Ground / 12.00 CASING DETAILS TVD MD Name 2514.10 2687.38 10-3/4" Surface Casing 5030.10 10037.69 7-5/8" Intermediate Casing 5056.10 21191.32 4-1/2" Production Liner Mag Model & Date: BGGM2024 01-Nov-24 Magnetic North is 14.01° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.63° 57195.31nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 700.00 3.00 355.00 699.91 5.21 -0.46 1.50 355.00 5.16 Start Build 2.00 4 1637.02 21.74 355.00 1611.10 204.30 -17.87 2.00 0.00 201.96 Start 107.66 hold at 1637.02 MD 5 1744.68 21.74 355.00 1711.10 244.02 -21.35 0.00 0.00 241.23 Start Build 2.00 6 2739.15 41.63 355.00 2553.10 761.77 -66.65 2.00 0.00 753.06 Start 20.00 hold at 2739.15 MD 7 2759.15 41.63 355.00 2568.05 775.01 -67.80 0.00 0.00 766.15 Start DLS 2.00 TFO 25.30 8 4449.81 73.33 9.38 3468.63 2174.28 17.67 2.00 25.30 2095.62 Start 4754.14 hold at 4449.81 MD 9 9203.95 73.33 9.38 4832.18 6667.85 759.63 0.00 0.00 6244.04 Start DLS 3.00 TFO -78.68 1010190.98 81.00 340.00 5055.93 7613.50 667.88 3.00 -78.68 7181.22 Start Build 2.00 11 10390.98 85.00 340.00 5080.30 7800.00 600.00 2.00 0.00 7378.93 Start 400.00 hold at 10390.98 MD 1210790.98 85.00 340.00 5115.16 8174.45 463.71 0.00 0.00 7775.89 Start DLS 2.00 TFO 78.16 1311041.23 86.04 344.91 5134.71 8412.25 388.54 2.00 78.16 8025.05 Start 486.77 hold at 11041.23 MD 1411528.00 86.04 344.91 5168.29 8881.12 262.11 0.00 0.00 8510.66 Start DLS 1.50 TFO 21.92 1511812.20 90.00 346.50 5178.10 9156.29 192.00 1.50 21.92 8794.60 3T-608 T02 Start DLS 1.50 TFO 29.53 1611851.76 90.52 346.79 5177.92 9194.78 182.87 1.50 29.53 8834.14 Start 5284.91 hold at 11851.76 MD 1717136.67 90.52 346.79 5130.30 14339.69 -1024.57 0.00 0.0014116.25 Start DLS 1.00 TFO -24.43 1817255.70 91.60 346.30 5128.10 14455.43 -1052.26 1.00 -24.4314235.22 3T-608 T03 Start DLS 1.00 TFO -36.08 1917349.52 92.36 345.75 5124.86 14546.41 -1074.90 1.00 -36.0814328.96 Start 1227.88 hold at 17349.52 MD 2018577.40 92.36 345.75 5074.34 15735.49 -1376.96 0.00 0.0015555.70 Start DLS 1.50 TFO 177.50 21 18734.76 90.00 345.85 5071.10 15888.00 -1415.55 1.50 177.5015713.00 3T-608 T04 Start DLS 1.50 TFO 0.29 2218758.20 90.35 345.85 5071.03 15910.72 -1421.28 1.50 0.2915736.43 Start 2433.12 hold at 18758.20 MD 23 21191.32 90.35 345.85 5056.10 18270.00 -2016.00 0.00 0.0018169.24 TD at 21191.32 FORMATION TOP DETAILS TVDPath Formation 1380.10 Top Ugnu C 1604.10 Top Ugnu B 1663.10 Base Permafrost 1702.10 Top Ugnu A 2004.10 Top West Sak 2493.10 Base West Sak 2548.10 C-80 2617.10 C-50 3764.10 C-35 4125.10 Top Coyote 4221.10 Base Coyote 5025.10 Top Torok By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by Plan 12+39.1 @ 51.10usft (D142) -25000250050007500True Vertical Depth0 2500 5000 7500 10000 12500 15000 17500 20000Vertical Section at 345.00°10-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner10002000300040005000600070008000900010000110001200 0 13 000 14 000 15000 16000 1700 0 18000 19000 20000 2100021192 0°30°60°73°85°86°90°91° 9 2 ° 90° 3T-608 wp13.1 Top Ugnu CTop Ugnu BBase PermafrostTop Ugnu ATop West SakBase West SakC-80C-50C-35Top Coyote (Nanushuk), K3Base Coyote (Nanushuk)Top Torok (Moraine)3T-608 wp13.116:36, September 03 2024Section View 035007000105001400017500South(-)/North(+)-14000 -10500 -7000 -3500 0 3500 7000 10500West(-)/East(+)3T-608 T05 0320243T-608 T023T-608 T033T-608 T043T-608 T01 04032410-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner50010001500200025003000350040004500500050563T-608 wp13.13T-608 wp13.1While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise.16:41, September 03 20243ODQ9LHZ 0.000.751.502.253.003.754.505.256.006.757.50Separation Factor0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 1375015000 16250 17500 18750 20000 21250Measured Depth (2500 usft/in)NDST-02/NDST-02PB13S-610/3S-6103S-617/3S-617ODSN-17/ODSN-1ODST-47/ODST-473T-603/3T-603 wp1Plan: 3T-605 CantwPlan: 3T-607 ChildPlan: 3T-610 DaisySTOP DrillingTake Immediate ActionCaution - Monitor CloselyNormal OperationsProject: Kuparuk River Unit_2Site: Kuparuk 3T PadWell: 3T-608Wellbore: 3T-608Design: 3T-608 wp13.1 0 30 60 Centre to Centre Separation0 450 900 1350 1800 2250 Partial Measured Depth3T-605 wp05 v53T-606 wp06 v53T-607 wp05 v53T-609 wp06 v53T-610 wp05 v5Equivalent Magnetic Distance 3T-608 wp13.1 Ladder View 0 150 300 Centre to Centre Separation0 3000 6000 9000 12000 15000 18000 21000 Measured DepthNDST-02NDST-02PB13T-603 wp13 - permit3T-601 wp05 v53T-602 wp05 v53T-604 wp05 v53T-605 wp05 v53T-606 wp06 v53T-607 wp05 v53T-609 wp06 v53T-610 wp05 v53T-611 wp06 v53T-612 wp123T-613 wp05 v53T-614 wp05 v53T-615 wp05 v53T-616 wp123T-617 wp05 v53T-618 wp05 v5ODST-47Equivalent Magnetic Distance SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.10 300.00 3T-608 wp13.1 (3T-608) INC 300.00 2680.00 3T-608 wp13.1 (3T-608) MWD+IFR2+SAG+MS 2680.0010030.00 3T-608 wp13.1 (3T-608) MWD+IFR2+SAG+MS 10030.00 21191.32 3T-608 wp13.1 (3T-608) MWD+IFR2+SAG+MS 16:47, September 03 2024 CASING DETAILS TVD MD Name 2514.10 2687.38 10-3/4" Surface Casing 5030.10 10037.69 7-5/8" Intermediate Casing 5056.10 21191.32 4-1/2" Production Liner 39 500 500 700 700 900 900 1300 1300 1600 1600 2000 2000 3000 3000 5000 5000 8000 8000 13000 13000 18000 18000 21192 3T-608 wp13.1 TC View 30 30 60 60 90 90 120 120 150 150 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in] 100200300400500 601 702 804 906 1009 3T-603 wp13 - permit 39100200300400500602703 3T-601 wp05 v5 39100200300400500 602 702 803 9023T-602 wp05 v5 100200300400500601 702 804 905 1007 1108 1209 3T-604 wp05 v5 39100200300400500601 702 803 904 1006 1107 1208 13103T-605 wp05 v5 39100200300400500601701802902 1002 1101 1200 1298 1396 1493 3T-606 wp06 v53910020030040050060170180290210031105120613081409151116131714 1815 1917 2020 2122 2225 2328 2432 2536 2640 2743 2848 3T-607 wp05 v5 391002003004005006007008008999991099119912991399 149915991699 179918991999209921992299239925002600 2700 280028982996309331893T-609 wp06 v5 3910020030040050060069979989999910991199129914001500160117011801190220032104220623073T-610 wp05 v5 391002003004005006006997978969941093119112881386 1483 1579 16763T-611 wp06 v5 39100200300400500599 698797895992 1089 1186 3T-612 wp12 391002003004005005996987968949921090 1188 3T-613 wp05 v5 39100200300400500 598 696 791 3T-614 wp05 v5 391002003004005005996977948923T-615 wp05 v5 391002003004003T-616 wp12 18898 18811 18725 18638 18549 ODST-47 SURVEY PROGRAM Date: 2024-03-21T00:00:00 Validated: Yes Version: From To Tool 39.10 300.00 INC 300.00 2680.00 MWD+IFR2+SAG+MS 2680.00 10030.00 MWD+IFR2+SAG+MS 10030.00 21191.32 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 2514.10 2687.38 10-3/4" Surface Casing 5030.10 10037.69 7-5/8" Intermediate Casing 5056.10 21191.32 4-1/2" Production Liner SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 700.00 3.00 355.00 699.91 5.21 -0.46 1.50 355.00 5.16 Start Build 2.00 4 1637.02 21.74 355.00 1611.10 204.30 -17.87 2.00 0.00 201.96 Start 107.66 hold at 1637.02 MD 5 1744.68 21.74 355.00 1711.10 244.02 -21.35 0.00 0.00 241.23 Start Build 2.00 6 2739.15 41.63 355.00 2553.10 761.77 -66.65 2.00 0.00 753.06 Start 20.00 hold at 2739.15 MD 7 2759.15 41.63 355.00 2568.05 775.01 -67.80 0.00 0.00 766.15 Start DLS 2.00 TFO 25.30 8 4449.81 73.33 9.38 3468.63 2174.28 17.67 2.00 25.30 2095.62 Start 4754.14 hold at 4449.81 MD 9 9203.95 73.33 9.38 4832.18 6667.85 759.63 0.00 0.00 6244.04 Start DLS 3.00 TFO -78.68 1010190.98 81.00 340.00 5055.93 7613.50 667.88 3.00 -78.68 7181.22 Start Build 2.00 11 10390.98 85.00 340.00 5080.30 7800.00 600.00 2.00 0.00 7378.93 Start 400.00 hold at 10390.98 MD 1210790.98 85.00 340.00 5115.16 8174.45 463.71 0.00 0.00 7775.89 Start DLS 2.00 TFO 78.16 1311041.23 86.04 344.91 5134.71 8412.25 388.54 2.00 78.16 8025.05 Start 486.77 hold at 11041.23 MD 1411528.00 86.04 344.91 5168.29 8881.12 262.11 0.00 0.00 8510.66 Start DLS 1.50 TFO 21.92 1511812.20 90.00 346.50 5178.10 9156.29 192.00 1.50 21.92 8794.60 3T-608 T02 Start DLS 1.50 TFO 29.53 1611851.76 90.52 346.79 5177.92 9194.78 182.87 1.50 29.53 8834.14 Start 5284.91 hold at 11851.76 MD 1717136.67 90.52 346.79 5130.30 14339.69 -1024.57 0.00 0.0014116.25 Start DLS 1.00 TFO -24.43 1817255.70 91.60 346.30 5128.10 14455.43 -1052.26 1.00 -24.4314235.22 3T-608 T03 Start DLS 1.00 TFO -36.08 1917349.52 92.36 345.75 5124.86 14546.41 -1074.90 1.00 -36.0814328.96 Start 1227.88 hold at 17349.52 MD 2018577.40 92.36 345.75 5074.34 15735.49 -1376.96 0.00 0.0015555.70 Start DLS 1.50 TFO 177.50 21 18734.76 90.00 345.85 5071.10 15888.00 -1415.55 1.50 177.5015713.00 3T-608 T04 Start DLS 1.50 TFO 0.29 2218758.20 90.35 345.85 5071.03 15910.72 -1421.28 1.50 0.2915736.43 Start 2433.12 hold at 18758.20 MD 23 21191.32 90.35 345.85 5056.10 18270.00 -2016.00 0.00 0.0018169.24 TD at 21191.32 3T-608 wp13.1AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.10 300.00 INC300.00 2680.00 MWD+IFR2+SAG+MS2680.00 10030.00 MWD+IFR2+SAG+MS10030.00 21191.32 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName2514.102687.3810-3/4" Surface Casing5030.1010037.697-5/8" Intermediate Casing5056.1021191.324-1/2" Production Liner1010202030304040505060600901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [20 usft/in]391002003004005006013T-605 wp05 v53910020030040050060170180290210023T-606 wp06 v53910020030040050060170180290210031105120613081409151116133T-607 wp05 v5391002003004005006007008008999991099119912991399149915991699179918991999209921993T-609 wp06 v539100200300400500600699799899999109911993T-610 wp05 v5391002003004005006003T-611 wp06 v539 500500 700700 900900 13001300 16001600 20002000 30003000 50005000 80008000 1300013000 1800018000 21192From Colour To MD39.10 To 2700.00MD Azi TFace39.10 0.00 0.00500.00 0.00 0.00700.00 355.00 355.001637.02 355.00 0.001744.68 355.00 0.002739.15 355.00 0.002759.15 355.00 0.004449.81 9.38 25.309203.95 9.38 0.0010190.98 340.00 -78.6810390.98 340.00 0.0010790.98 340.00 0.0011041.23 344.91 78.1611528.00 344.91 0.0011812.20 346.50 21.9211851.76 346.79 29.5317136.67 346.79 0.0017255.70 346.30 -24.4317349.52 345.75 -36.0818577.40 345.75 0.0018734.76 345.85 177.5018758.20 345.85 0.2921191.32 345.85 0.00 3T-608 wp13.1AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.10 300.00 INC300.00 2680.00 MWD+IFR2+SAG+MS2680.00 10030.00 MWD+IFR2+SAG+MS10030.00 21191.32 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName2514.102687.3810-3/4" Surface Casing5030.1010037.697-5/8" Intermediate Casing5056.1021191.324-1/2" Production Liner3030606090901201201501501801800901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]8739882489068984NDST-02760577017798789579928089NDST-02PB1264027432848295430603166327333804646474448414939503751343T-607 wp05 v5260027002800289829963093318932853T-609 wp06 v526113T-610 wp05 v539 500500 700700 900900 13001300 16001600 20002000 30003000 50005000 80008000 1300013000 1800018000 21192From Colour To MD2600.00 To 10100.00MD Azi TFace39.10 0.00 0.00500.00 0.00 0.00700.00 355.00 355.001637.02 355.00 0.001744.68 355.00 0.002739.15 355.00 0.002759.15 355.00 0.004449.81 9.38 25.309203.95 9.38 0.0010190.98 340.00 -78.6810390.98 340.00 0.0010790.98 340.00 0.0011041.23 344.91 78.1611528.00 344.91 0.0011812.20 346.50 21.9211851.76 346.79 29.5317136.67 346.79 0.0017255.70 346.30 -24.4317349.52 345.75 -36.0818577.40 345.75 0.0018734.76 345.85 177.5018758.20 345.85 0.2921191.32 345.85 0.00 3T-608 wp13.1AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.10 300.00 INC300.00 2680.00 MWD+IFR2+SAG+MS2680.00 10030.00 MWD+IFR2+SAG+MS10030.00 21191.32 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName2514.102687.3810-3/4" Surface Casing5030.1010037.697-5/8" Intermediate Casing5056.1021191.324-1/2" Production Liner454590901351351801802252252702700901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [90 usft/in]19252191631907418986188981881118725186381854918461183721828218192ODST-4739 500500 700700 900900 13001300 16001600 20002000 30003000 50005000 80008000 1300013000 1800018000 21192From Colour To MD10000.00 To 21192.00MD Azi TFace39.10 0.00 0.00500.00 0.00 0.00700.00 355.00 355.001637.02 355.00 0.001744.68 355.00 0.002739.15 355.00 0.002759.15 355.00 0.004449.81 9.38 25.309203.95 9.38 0.0010190.98 340.00 -78.6810390.98 340.00 0.0010790.98 340.00 0.0011041.23 344.91 78.1611528.00 344.91 0.0011812.20 346.50 21.9211851.76 346.79 29.5317136.67 346.79 0.0017255.70 346.30 -24.4317349.52 345.75 -36.0818577.40 345.75 0.0018734.76 345.85 177.5018758.20 345.85 0.2921191.32 345.85 0.00 3T-608 wp13.1Spider Plot7:44, September 04 202439.10 To 21191.90Northing (6500 usft/in)Easting (6500 usft/in)405060Colville Delta 24050NDST-024050NDST-02PB140503S-61040503S-6174 0 50 60ODSN-174 0 50 60ODSN-17L14050ODST-4740503T-603 wp13 - permit405 03T-6214 0503T-601 wp05 v54 0503T-602 wp05 v540503T-604 wp05 v540503T-605 wp05 v540503T-606 wp06 v540503T-607 wp05 v540503T-609 wp06 v540503T-610 wp05 v540503T-611 wp06 v540503T-612 wp1240503T-613 wp05 v540503T-614 wp05 v540503T-615 wp05 v54 0 503T-616 wp1240503T-617 wp05 v540503T-618 wp05 v540503T-619 wp06 v540503T-620 wp05 v540503T-622 wp05 v540503T-623 wp05 v540503T-624 wp05 v540503T-625 wp05 v540503T-626 wp05 v540503T-627 wp05 v540 503T-628 wp05 v540503T-629 wp05 v5403T-730 (I14) wp08 403T-731 (P14) wp0840503T-608 wp13.1 3T-608 wp13.1Spider Plot7:53, September 04 202439.10 To 21191.90Northing (2500 usft/in)Easting (2500 usft/in)3035404550NDST-023035404550NDST-02PB13S-6103S-61730354045503T-603 wp13 303540455 0553T-6213 0 3 5 4 0 4 5503T-601 wp05 v53 0 3 5 4 0 4 5503T-602 wp05 v530354045503T-604 wp05 v530354045503T-605 wp05 v530354045503T-606 wp06 v530354045503T-607 wp05 v530354045503T-609 wp06 v530354045503T-610 wp05 v530354045503T-611 wp06 v530354045503T-612 wp1230354045503T-613 wp05 v53T-614 wp05 v53035404 5 503T-615 wp05 v53T-616 wp1230354045503T-617 wp05 v53035404 5 503T-618 wp05 v530354045503T-619 wp06 v53035404 5 503T-620 wp05 v530354045503T-622 wp05 v53035404 5 503T-623 wp05 v530354045503T-624 wp05 v530354045503T-625 wp05 v53035404 5 503T-626 wp05 v53T-627 wp05 v53 0 3 5 40 45 503T-628 wp05 v530354045503T-629 wp05 v53035403T-730 (I14) wp083035403T-731 (P14) wp0830354045503T-608 wp13.1 3T-608 wp13.1Spider Plot7:58, September 04 202439.10 To 21191.90Northing (1500 usft/in)Easting (1500 usft/in)26283032343638404244464850NDST-022628303234363840424446485052NDST-02PB13S-6103S-617262830323436384042444648503T-603 wp13 2628303234363840424446485 052543T-6212 6 2 8 3 0 3 2 3 4 3 6 3 8 4 0 4 2 4 4 4 64850523T-601 wp05 v52 6 2 8 3 0 3 2 3 4 3 6 3 8 4 0 4 2 4 4 4 64850523T-602 wp05 v5262830323436384042444648503T-604 wp05 v5262830323436384042444648503T-605 wp05 v5262830323436384042444648503T-606 wp06 v5262830323436384042444648503T-607 wp05 v5262830323436384042444648503T-609 wp06 v5262830323436384042444648503T-610 wp05 v5262830323436384042444648503T-611 wp06 v5262830323436384042444648503T-612 wp122628303234363840423T-613 wp05 v53T-614 wp05 v52628303234363T-615 wp05 v53T-616 wp12262830323436384042444648507 wp05 v52628303234363T-618 wp05 v52628303234363840423T-619 wp06 v526283032343T-620 wp05 v526283032343638403T-622 wp05 v526283032343T-623 wp05 v52628303234363T-624 wp05 v52628303234363T-625 wp05 v5262830323T-626 wp05 v53T-627 wp05 v52628 3 0 3 23T-628 wp05 v528303234363T-629 wp05 v5262 83 032343T-730 (I14) wp082 628303234 363T-731 (P14) wp08262830323436384042444648503T-608 wp13.1 3T-608 wp13.1Spider Plot8:01, September 04 202439.10 To 21191.90Northing (300 usft/in)Easting (300 usft/in)1416182022NDST-021416182022NDST-02PB13S-6101416182022243T-603 wp13 1416182022243T-6211416 1 8 2 0 2 2 2 4 2 63T-601 wp05 v51 4 1 6 1 8 2 0 2 2 2 43T-602 wp05 v5141618202224263T-604 wp05 v5141618202224263T-605 wp05 v51416182022242628303T-606 wp06 v514161820222426283T-607 wp05 v51416182022242628303T-609 wp06 v51416182022242628303T-610 wp05 v514161820222426283032343T-611 wp06 v514161820222426283T-612 wp1214161820222426283T-613 wp05 v5143T-614 wp05 v5141618202224263T-615 wp05 v5143T-616 wp121416182022242628303T-617 wp05 v5141618202224263T-618 wp05 v514161820222426283T-619 wp06 v5141618202224263T-620 wp05 v5141618202224263T-622 wp05 v51416182022243T-623 wp05 v51416182022243T-624 wp05 v51416182022243T-625 wp05 v514161820223T-626 wp05 v53T-627 wp05 v51416182022243T-628 wp05 v51416182022243T-629 wp05 v5141618202224262 8 303234363T-730 (I14) wp081416182022242 62830 323436383T-731 (P14) wp081416182022242628303T-608 wp13.1 3T-608 wp13.1Spider Plot8:06, September 04 202439.10 To 21191.90Northing (50 usft/in)Easting (50 usft/in)02468103T-603 wp13 2468103T-601 wp05 v524 6 8 1 03T-602 wp05 v50246810123T-604 wp05 v5246810123T-605 wp05 v524681012143T-606 wp06 v524681012143T-607 wp05 v52468101214163T-609 wp06 v524681012143T-610 wp05 v5246810121416183T-611 wp06 v524681012143T-612 wp1224681012143T-613 wp05 v524683T-614 wp05 v5246810123T-615 wp05 v52463T-616 wp12246810123T-617 wp05 v568103T-618 wp05 v52468101214163T-608 wp13.1 3T-608 wp13.1Colville Delta 2NDST-02NDST-02PB13S-6103S-6173T-603 wp13 - permit3T-601 wp05 v53T-602 wp05 v53T-604 wp05 v53T-605 wp05 v53T-606 wp06 v53T-607 wp05 v53T-609 wp06 v53T-610 wp05 v53T-611 wp06 v53T-612 wp123T-613 wp05 v53T-616 wp123T-617 wp05 v5ODSN-17ODSN-17L1ODST-473-D View3T-608 wp13.117:07, September 03 2024 3T-608 wp13.1Colville Delta 2NDST-02NDST-02PB13S-6103S-6173T-603 wp13 - permit3T-601 wp05 v53T-602 wp05 v53T-604 wp05 v53T-605 wp05 v53T-606 wp06 v53T-607 wp05 v53T-609 wp06 v53T-610 wp05 v53T-611 wp06 v53T-614 wp05 v53T-616 wp123T-617 wp05 v5ODSN-17ODSN-17L1ODST-473-D View3T-608 wp13.117:08, September 03 2024 6000900012000150001800021000South(-)/North(+) (3000 usft/in)-12000 -9000 -6000 -3000 0 3000 6000 9000 12000West(-)/East(+) (3000 usft/in)505051005150Colville Delta 2505051005150NDST-02505051005150NDST-02PB13S-6103S-617ODSN-17ODSN-17L1505051005150ODST-475050510051503T-603 wp13 51503T-601 wp05 v53T-602 wp05 v55050510051503T-604 wp05 v55050510051503T-605 wp05 v55050510051503T-606 wp06 v55050510051503T-607 wp05 v55050510051503T-609 wp06 v55050510051503T-610 wp05 v53T-611 wp06 v53T-612 wp125050510051503T-613 wp05 v53T-614 wp05 v53T-615 wp05 v53T-616 wp123T-617 wp05 v55050510051503T-619 wp06 v53T-622 wp05 v53T-624 wp05 v53T-625 wp05 v53T-629 wp05 v57-5/8"4-1/2" Production Liner5050510051503T-608 wp13.13T-608 wp13.1Quarter Mile View8:17, September 04 2024WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T-608 T02 5178.10 Circle (Radius: 100.00)3T-608 T03 5128.10 Circle (Radius: 100.00)3T-608 T04 5071.10 Circle (Radius: 100.00)3T-608 T01 040324 5032.10 Circle (Radius: 100.00)3T-608 T01 QM 5032.10 Circle (Radius: 1350.00)3T-608 T02 QM 5178.10 Circle (Radius: 1350.00)3T-608 T03 QM 5128.10 Circle (Radius: 1350.00)3T-608 T05 032024 5126.07 Circle (Radius: 100.00)3T-608 T05 QM 5126.07 Circle (Radius: 1350.00) 6000900012000150001800021000South(-)/North(+) (3000 usft/in)-12000 -9000 -6000 -3000 0 3000 6000 9000 12000West(-)/East(+) (3000 usft/in)505051005150Colville Delta 2505051005150NDST-02505051005150NDST-02PB13S-6103S-617505051005150ODST-475050510051503T-603 wp13 5050510051503T-607 wp05 v57-5/8"4-1/2" Production Liner5050510051503T-608 wp13.13T-608 wp13.1Quarter Mile View8:22, September 04 2024WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T-608 T02 5178.10 Circle (Radius: 100.00)3T-608 T03 5128.10 Circle (Radius: 100.00)3T-608 T04 5071.10 Circle (Radius: 100.00)3T-608 T01 040324 5032.10 Circle (Radius: 100.00)3T-608 T01 QM 5032.10 Circle (Radius: 1350.00)3T-608 T02 QM 5178.10 Circle (Radius: 1350.00)3T-608 T03 QM 5128.10 Circle (Radius: 1350.00)3T-608 T05 032024 5126.07 Circle (Radius: 100.00)3T-608 T05 QM 5126.07 Circle (Radius: 1350.00) WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T-608 T02 5178.10 Circle (Radius: 100.00)3T-608 T03 5128.10 Circle (Radius: 100.00)3T-608 T04 5071.10 Circle (Radius: 100.00)3T-608 Srf Csg 2514.10 Circle (Radius: 500.00)3T-608 T01 040324 5032.10 Circle (Radius: 100.00)3T-608 T01 QM 5032.10 Circle (Radius: 1350.00)3T-608 T02 QM 5178.10 Circle (Radius: 1350.00)3T-608 T03 QM 5128.10 Circle (Radius: 1350.00)3T-608 T05 0320245126.07 Circle (Radius: 100.00)3T-608 T05 QM 5126.07 Circle (Radius: 1350.00)-450045090013501800South(-)/North(+) (450 usft/in)-1350 -900 -450 0 450 900 1350 1800West(-)/East(+) (450 usft/in)25253T-603 wp13 - permit25253T-6212 5253T-601 wp05 v52 5253T-602 wp05 v525253T-604 wp05 v525253T-605 wp05 v525253T-606 wp06 v525253T-607 wp05 v525253T-609 wp06 v525253T-610 wp05 v525253T-611 wp06 v525253T-612 wp1225253T-613 wp05 v53T-614 wp05 v525253T-615 wp05 v53T-616 wp1225253T-617 wp05 v525253T-618 wp05 v525253T-619 wp06 v525253T-620 wp05 v525253T-622 wp05 v525253T-623 wp05 v525253T-624 wp05 v525253T-625 wp05 v525253T-626 wp05 v53T-627 wp05 v525253T-628 wp05 v525253T-629 wp05 v525253T-730 (I14) wp082525 3T-731 (P14) wp0810-3/4" Surface Casing25253T-608 wp13.13T-608 wp13.1Surface Casing 500'r8:38, September 04 2024 WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T-608 T02 5178.10 Circle (Radius: 100.00)3T-608 T03 5128.10 Circle (Radius: 100.00)3T-608 T04 5071.10 Circle (Radius: 100.00)3T-608 Srf Csg 2514.10 Circle (Radius: 500.00)3T-608 T01 040324 5032.10 Circle (Radius: 100.00)3T-608 T01 QM 5032.10 Circle (Radius: 1350.00)3T-608 T02 QM 5178.10 Circle (Radius: 1350.00)3T-608 T03 QM 5128.10 Circle (Radius: 1350.00)3T-608 T05 0320245126.07 Circle (Radius: 100.00)3T-608 T05 QM 5126.07 Circle (Radius: 1350.00)-450045090013501800South(-)/North(+) (450 usft/in)-1350 -900 -450 0 450 900 1350 1800West(-)/East(+) (450 usft/in)10-3/4" Surface Casing25253T-608 wp13.13T-608 wp13.1Surface Casing 500'r8:39, September 04 2024 3T-608wp13.1 Surface Location 3T-608wp13.1 Surface Location Schlumberger-Confidential 3T-608wp13.1 Surface Casing 3T-608wp13.1 Surface Casing Schlumberger-Confidential 3T-608wp13.1 Intermediate Csg 3T-608wp13.1 Intermediate Csg Schlumberger-Confidential 3T-608wp13.1 Top Torok (Moraine) 3T-608wp13.1 Top Torok (Moraine) Schlumberger-Confidential 3T-608wp13.1 TD 3T-608wp13.1 TD Schlumberger-Confidential 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. KRU 3T-608 TOROK OIL KUPARUK RIVER 224-094 WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 3T-608Initial Class/TypeSER / PENDGeoArea890Unit11160On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2240940KUPARUK RIVER, TOROK OIL - 490169NA1Permit fee attachedYesADL025528 and ADL3938832Lease number appropriateYes3Unique well name and numberYesKUPARUK RIVER, TOROK OIL - 490169 - governed by CO 725A4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitYesAIO 39A14Well 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)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes81' driven conductor18Conductor string providedYesSC set at 2686' MD19Surface casing protects all known USDWsYes152% excess cement planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgYesProductive interval will be completed with cemented liner22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedYes27If diverter required, does it meet regulationsYesMax formation pressure is 2316 psig(8.8 ppg EMW); will drill w/ 9.0-9.5 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 1798 psig; will test BOPs to 5000 psig initially and 4000 psig subsequently30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYes33Is presence of H2S gas probableYes34Mechanical condition of wells within AOR verified (For service well only)NoMeasures required. 70 ppm recorded at adjacent 3S-610 (2024)35Permit can be issued w/o hydrogen sulfide measuresYesAnticipated pore pressure for Moraine and Coyote is 8.6 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]ApprADDDate9/27/2024ApprVTLDate9/30/2024ApprADDDate9/27/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 9/30/2024 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re: Kuparuk River Field, Torok Oil Pool, KRU 3T-608 Conoco Phillips Alaska, Inc. Permit to Drill Number: 224-094 Surface Location: 1943' FSL, 596' FWL, SENE S1 T12N R7E Bottomhole Location: 4372' FSL, 181' FWL, SENW S23 T13N R7E 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 Chmielowski Commissioner DATED this 13th day of August 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.13 16:09:28 -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: 21191 TVD: 5126 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: 8/20/2024 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 908' to ADL355036 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 51.1 15. Distance to Nearest Well Open Surface: x-6003669 y- 467806 Zone- 4 12 to Same Pool: 772' to 3S-617 16. Deviated wells:Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42"20" 94 H-40 Welded 80.9 39.1 39.1 120 120 13.5"10.75" 45.5 L80 Hyd563 2647.9 39.1 39.1 2687 2514 9.875"7.625" 29.7 L80 Hyd563 9066.9 39.1 39.1 9106 4806 9.875"7.625" 33.7 P110-S Hyd563 800 9106 4806 9906 5005 6.5"4.5" 12.6 P110-S Hyd563 11435 9756 5091 21191 5126 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: Brian Broussard Chris Brillon Contact Email:Brian.T.Broussard@cop.com Wells Engineering Manager Contact Phone:907-263-4090 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10 yds P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field Torok Oil Pool 1943' FSL, 596' FWL, SENE S1 T12N R7E ADL025528 / ADL393883 (including stage data) 4106' FSL, 2905' FWL, NWSE S35 T13N R7E LONS 01-013 4372' FSL, 181' FWL, SENW S23 T13N R7E 2560 / 5760 GL / BF Elevation above MSL (ft): 2316 1798 18. Casing Program: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ConocoPhillips Alaska Inc.59-52-180 3T-608 940sks 10.7ppg, 280sks 15.8ppg 1000sks 15.3ppg Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Casing Length Size Cement Volume MD Total Depth MD (ft):Total Depth TVD (ft):Plugs (measured):Effect. Depth MD (ft):Effect. Depth TVD (ft): Surface Conductor/Structural Liner Production Intermediate Perforation Depth MD (ft):Perforation Depth TVD (ft): 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: Commission Use Only See cover letter for other requirements. s N yp L l R S os N s Noo s N o D s s sD 0 o p G S S 20 S s No s No S G E s No s Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Grace Christianson at 9:08 am, Jul 10, 2024 KRU Initial BOP test to 5000 psig; subsequent BOP test to 4000 psig Annular preventer test to 2500 psig BOPE testing on a 21-day interval is approved with the attached conditions 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 DSR_8/12/24A.Dewhurst 22JUL24 224-094 X 50-103-20890-00-00 -A.Dewhurst 18JUL24X: 467,806' Y: 6,003,669' VTL 8/12/2024 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.13 16:09:41 -08'00' 08/13/24 08/13/24 RBDMS JSB 081524 .58'67 CPAI’s request to allow BOPE testing on a 21-day interval is approved with the following conditions: - CPAI must continue to implement the Between Wells Maintenance Program as approved by AOGCC. - The initial test after rigging up BOPE to drill a well must be to the rated working pressure as provided in API Standard 53. - CPAI is encouraged to take advantage of opportunities to test within the 21-day time limit. - CPAI must adhere to original equipment manufacturer recommendations and replacement parts for BOPE. - Requests for extensions beyond 21 days must include justification with supporting information demonstrating the additional time is necessary for well control purposes or to mitigate a stuck drill string. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 3, 2024 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill 3T-608 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Moraine Injector well from the 3T drilling pad. The intended spud date for this well is 8/20/2024. It is intended that Doyon 142 be used to drill the well. 3T-608 will utilize a 13 1/2” surface hole drilled to TD and 10 3/4” casing will be set and cemented to surface. As noted in section 4 of the attached proposed drilling program, the low maximum anticipated surface pressure of the well allows use of a three preventer BOPE per 20 AAC 25.035 (e) (1) (A) (i-iii). The fourth preventer will contain solid body pipe rams that will be sized for the intermediate casing string. The 9 7/8” intermediate hole will be drilled and topset the Moraine reservoir. A 7 5/8” casing string will be set and cemented from TD to secure the shoe and cover 250’TVD above any hydrocarbon-bearing zones (Coyote). The production interval will be comprised of a 6 1/2” horizontal hole that will be landed and geo-steered in the Moraine formation. The well will be completed as an uncemented, fracture stimulated Injector with 4 1/2” liner, frac sleeves and swell packers. The upper completion will include a production packer with GLM’s and a downhole guage tied back to surface. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Brian Broussard at 907-263-4090 (Brian.T.Broussard@conocophillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: 3T-608 Well File / Jenna Taylor ATO 1560 David Lee ATO 1552 Brian Broussard Chris Brillon ATO 1548 Drilling Engineer Roland Kirschner ATO 636 Brian Broussard I am the author of this document 2024.07.09 16:18:27-08'00' Brian Broussard 3T-608 Application for Permit to Drill Document Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................................................ 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................................................... 2 3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) ........................................................ 1 4. Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3)) ............................................. 1 5. Diverter System (Requirements of 20 AAC 25.005(c)(7)) ..................................................................... 2 6. MASP Calculations (Requirements of 20 AAC 25.005(c)(4)) ................................................................ 3 7. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) ............. 4 8. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) ........................................... 4 9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................................................. 5 10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ........................ 5 11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) ................................................................... 6 12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ................................................... 6 13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ............................................................. 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) ........................................................................................................................................................... 6 15. Drilling Hazards Summary ................................................................................................................. 6 16. Proposed Completion Schematic ....................................................................................................... 8 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as 3T-608 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 1,943 FSL, 596 FWL, SENE S1 T12N R7E, UM NAD 1927 Northings: 467806 Eastings:6003669 RKB Elevation 51.1’AMSL Pad Elevation 12’AMSL Top of Productive Horizon (Heel) 4106‘ FSL, 2905‘ FWL, NWSE S35 T13N R7E, UM NAD 1927 Northings: 468560 Eastings: 6011109 Measured Depth, RKB: 9,906 Total Vertical Depth, RKB: 5,005 Total Vertical Depth, SS: 4,954 Total Depth (Toe) 4372‘ FSL, 181‘ FWL, SENW S23 T13N R7E, UM NAD 1927 Northings: 465871 Eastings: 6021945 Measured Depth, RKB: 21,191 Total Vertical Depth, RKB: 5,126 Total Vertical Depth, SS: 5,075 Pad Layout 468,560' 465,871' 6,021,945' 6,003,669' 467,806' 6,011,109' -A.Dewhurst 18JUL24 3T-608 Area of Review (AOR) An Area of Review plot is show below of the 3T-608 injector planned wellpath and offset wells. 3S-610, NDST-02, NDST-02PB1, Colville Delta 2, and ODST-47 are the offset wells from the planned 3T-608. injector. Area of Review superseded by updated verision. -A.Dewhurst 22JUL24 Application for Permit to Drill, 3T-608 Saved: 8-Jul-24 3T-608 PTD Page 1 of 9 Printed: 8-Jul-24 Area of Review superseded by updated verision. -A.Dewhurst 22JUL24 Attachment 1 – 3T-608 Area of Review (AOR) An Area of Review plot is show below of the 3T-608 injector planned wellpath and offset wells. 3S-617, 3S-610, NDST-02, NDST-02PB1, Colville Delta 2, and ODST-47 are the offset wells from the planned 3T- 608. injector. PTD API Well Name Status Top of Zone-of-Interest Isolating Stage TOC Method TOC Determination Losses (volume, % no reported) Returns verified Zonal Isolation Comments 223-085 5010320864 3S-617 Producing 8,432’ MD 7-5/8”Intermediate Cement 3,841’ MD Ultrasonic CBL None Yes Yes Will continue producing during 3T-608 execution 223-126 501032087500 3S-610 Producing 9,171’ MD 7-5/8”Intermediate Cement 3,549’ MD Ultrasonic CBL None Yes Yes Will continue producing during 3T-608 execution 212-163 501032066000 NDST-02 Suspended 9,907’ MD Intermediate RBP at 2,000’ MD. 8,907’ MD Pressure Test RBP to 2,500 psi for 30 min None No No Scheduled for lateral abandonment in August 2024, and final P&A in Q1 2024. 212-163 501032066070 NDST-02PB1 P&A’d 8,650’ MD Open Hole Cement Plug 6,287’ MD Physical Tag None, full returns Yes Yes Pilot Hole. Abandonment plug and kickoff plug set 85-0210 501032004700 Colville Delta 2 P&A’d 6,233’ MD Surface and Intermediate Cement Plug/Squeeze. Surface Visual/Cement Retainers None, full returns Yes Yes Exploration well P&A’d in 1986. 9-5/8” cut and welded with plate 212-103 507032066000 ODST-47 Suspended 12,723’ MD 4-1/2” liner TAplug 12,223’ MD Pressure test to 3,000 psi None. Squeezed 191 bbl cement in lateral No. 9 bbl balanced cement plug Yes Will create geological separation by drilling into the upper Moraine. (ODST-47 is in lower Moraine) Application for Permit to Drill, 3T-608 Saved: 8-Jul-24 3T-608 PTD Page 1 of 9 Printed: 8-Jul-24 3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 142 onto 3T-608 2. Rig up and test diverter and riser, dewater cellar as needed. 3. Drill 13 1/2” hole to the surface casing point as per the directional plan. 4. Run and cement 10 3/4” surface casing to surface. 5. Install BOPE and MPD equipment. 6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr regulatory notice). 7. Pick up and run in hole with 9 7/8” drilling BHA to drill the intermediate hole section. 8. Chart casing pressure test to 3,000 psi for 30 minutes. 9. Drill out 20’ of new hole and perform LOT. Maximum LOT to 18.0 ppg. Minimum LOT required to drill ahead is 11.0 ppg EMW. 10. Drill 9 7/8” hole to section TD, setting pipe above the Moraine Reservoir. (LWD Program: GR/RES). 11. Run 7 5/8” casing and cement to a minimum of 250’ TVD above any hydrocarbon bearing zones (cementing schematic attached). Pressure test casing if possible on plug bump to 4000 psi. 12. Test BOPE to 250 psi low / 4,000 psi high (24-48 Regulatory notice). 13. Pick up and run in hole with 6 1/2” drilling BHA. Log top of cement with sonic tool in recorded mode. 14. Chart casing pressure test to 4,000 psi for 30 minutes if not tested on plug bump. 15. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 14.5 ppg. Minimum required leak- off value is 11.0 ppg EMW. 16. Drill 6 1/2” hole to section TD (LWD Program: GR/RES/Den/Neu/Sonic). 17. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC. 18. Run 4 1/2” liner with toe valve, frac sleeves and swell packers and liner hanger to TD. 19. Run 4 1/2” upper completion with glass plug, production packer, chemical injection mandrel with cap string, downhole gauge, and gas lift mandrels. Space out and land tubing hanger with pre-installed and pre-tested BPV. 20. Pressure test hanger seals to 3,850 psi. 21. Pressure test against the glass plug to set production packer, test tubing to 3,850 psi, chart test. 22. Bleed tubing pressure to 2200 psi and test IA to 3,850 psi, chart test. 23. Install HP-BPV and test to 2500 psi. 24. Nipple down BOP. 25. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes. 26. Freeze protect down tubing and annulus. 27. Secure well. Rig down and move out. Please note – This well will be frac’d 4. Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Doyon 142. Doyon 142 will use a BOPE stack equipped with an annular preventer, fixed 7 5/8” solid body rams, blind/shear rams and variable rams while drilling and running casing in the intermediate section of 3T-608. 3T-608 has a MASP of 1,780 psi in the intermediate hole section using the methodology in section 6 MASP calculations. With a MASP less than 3000 psi ConocoPhillips classifies the operation as a Class 2. Per 20AAC 25.035.e.a.A: For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including: i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except that pipe rams need not be sixed to bottom-hole assemblies and drill collars. ii. One with blind rams iii. One annular type Intermediate Drilling/Casing Production Proposed Configuration: Proposed Configuration: Annular Preventer (iii) Annular Preventer 7 5/8” fixed rams during drilling Intermediate VBRs in Upper Cavity Blind/Shear Rams (ii) Blind/Shear Rams VBRs (i) VBRs in Lower Cavity 5. Diverter System (Requirements of 20 AAC 25.005(c)(7)) A diverter will be utilized as there are no offset wells with surface shoes within 500’ of 3T-608. However, no hydrates are anticipated, and 3T-621 was recently drilled with no indications of hydrates occurring. Below is a schematic showing the planned location and 75’ exclusion zone of the diverter. 6. MASP Calculations (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Csg Setting Depth MD/TVD(ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) 20 119.1 / 119.1 10.9 53 56 10 3/4 2,687 / 2,514 13.5 1,124 1,513 7 5/8 9906 / 5,005 13.5 2,238 1,780 4 1/2 21,191 / 5,126 13.0 2,292 1,798 PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20” conductor ASP = [(FG x 0.052) – 0.1] D = [(10.9 x 0.052) – 0.1] x 119.1 = 56 psi OR ASP = FPP – (0.1 x D) = 1,124 – (0.1 x 2,514 ) = 873 psi 2. Drilling below 10.75” surface casing ASP = [(FG x 0.052) – 0.1] D = [(13.5 x 0.052) – 0.1] x 2,514 = 1,513 psi OR ASP = FPP – (0.1 x D) = 2,238 – (0.1 x 5,005 ) = 1,738 psi 3. Drilling below 7.625” intermediate casing ASP = [(FG x 0.052) – 0.1] D = [(13.0 x 0.052) – 0.1] x 5,126 = 2,953 psi OR ASP = FPP – (0.1 x D) = 2,292 – (0.1 x 5,126 )= 1,798 psi (B) data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 7. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out the casing shoe and perform LOT/FIT as per the procedure that ConocoPhillips Alaska has on file with the Commission. 8. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 20 42 94 H40 Welded Cemented to surface with 10 yds slurry 10 3/4 13 1/2 45.50 L80 Hyd563 Cement to Surface 7 5/8 9 7/8 29.70 33.70 L80 P110-S Hyd563 250’ TVD or 500’ MD, whichever is greater, above upper most producing zone (Coyote) 4 1/2 6 1/2 12.60 P110-S Hyd563 Unemented liner with frac sleeves and swell packers Cementing Calculations 10 3/4” Surface Casing run to 2,687 ’ MD / 2,514 ’ TVD Cement 2,687 MD to 2,187 (500’ of tail) with Class G + Add's@ 15.8 PPG, and from 2,187' to surface with 10.7 ppg Arctic Lite Crete. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1,693 ’ MD), zero excess in 20” conductor. Lead slurry from 2,187’ MD to surface with Arctic Lite Crete @ 10.7 ppg Total Volume = 2,733ft3 => 940 sx of 10.7 ppg Class G + Add's @ 2.92 ft3 /sk Tail slurry from 2,687 MD to 2,187’ MD with 15.8 ppg Class G + Add's Total Volume = 316 ft3 => 280 sx of 15.8ppg Class G + Add's @ 1.16 ft3/sk 7 5/8” Intermediate Casing run to 9906’ MD / 5,005 ’ TVD Top of slurry is designed to be at 5,866 ’ MD, which is 250’ TVD above the prognosis shallowest hydrocarbon bearing zone, Coyote. If a shallower hydrocarbon zone of producible volumes, is encountered while drilling, a 2-stage cement job will be performed to isolate this zone. Assume 40% excess annular volume. Tail slurry from 9,906 MD to 5,866’ MD with 15.3 ppg Class G + Add's Total Volume = 1,235 ft3 => 1000 sx of 15.3 ppg Class G + Add's @ 1.2455 ft3/sk 9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate Production Hole Size in. 13 1/2 9 7/8 6 1/2 Casing Size in. 10 3/4 7 5/8 4 1/2 Density PPG 8.6 – 9.8 9.0 – 9.6 9.0 – 9.5 PV cP 20-50 8-15 7-12 YP lb./100 ft2 30 - 80 20 - 30 15 - 30 Funnel Viscosity s/qt. 250 – 300 40-60 35-50 Initial Gels lb./100 ft2 30 - 50 8 - 15 5- 10 10 Minute Gels lb./100 ft2 50 - 70 <20 7 - 15 API Fluid Loss cc/30 min. N.C. – 15.0 < 10.0 < 6.0 HPHT Fluid Loss cc/30 min. N/A < 10.0 < 10.0 pH 9.5 – 10.0 9.5 – 10.0 9.5 – 10.5 Surface Hole: A water based spud mud will be used for the surface interval. Mud engineer to perform regular mud checks to maintain proper specifications The mud weight will be maintained at 9.8 ppg by use of solids control system and dilutions where necessary. Intermediate: Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight at or below 9.6 ppg for formation stability and be prepared to add loss circulation material if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important. The mud will be weighted up to 9.5 ppg before pulling out of the hole. Production Hole: The horizontal production interval will be drilled with an inhibited fresh water polymer mud system weighted to 9.0 – 9.5 ppg. MPD will be available for adding backpressure during connections if necessary. Diagram of Doyon 142 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Drilling Hazards Summary 13 1/2" Hole / 10 3/4” Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Follow real time surveys very closely, gyro survey as needed to ensure survey accuracy. Gas Hydrates Low If observed – control drill, reduce pump rates and circulating time, reduce mud temperatures Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Running sands and gravels Low Maintain planned mud properties, increase mud weight, use weighted sweeps 9 7/8” Hole /7 5/8” Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale / Tight hole / Stuck Pipe Low Good hole cleaning, pre-treatment with LCM, stabilized BHA, maintain planned mud weights and adjust as needed, real time equivalent circulating density (ECD) monitoring Lost circulation Moderate Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring, Liner will be in place at TD Abnormal Reservoir Pressure (Coyote / K3) Low Well control drills, check for flow during connections, increase mud weight if necessary 6 1/2” Hole / 4 1/2” Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Moderate Reduce pump rates, real time ECD monitoring, maintain mud rheology, add lost circulation material Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Moderate Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Running Liner to Bottom Moderate Properly clean hole on the trip out with BHA, perform clean out run if necessary, utilize super sliders for weight transfer if needed, monitor T&D real time Well Proximity Risks: 3T is a multi-well pad, with only a few existing wells. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Unlikely to encounter any abnormal pressure, however, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. The overburden logs will be evaluated to ensure no hydrocarbon bearing zones are above the known Coyote. If identified, the primary intermediate cement job will be replanned to cover the zone as per the agency regulations. Lost Circulation: Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. 16. Proposed Completion Schematic SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 700.00 3.00 355.00 699.91 5.21 -0.46 1.50 355.00 5.16 Start Build 2.00 4 1637.02 21.74 355.00 1611.10 204.30 -17.87 2.00 0.00 201.96 Start 107.66 hold at 1637.02 MD 5 1744.68 21.74 355.00 1711.10 244.02 -21.35 0.00 0.00 241.23 Start Build 2.00 6 2739.15 41.63 355.00 2553.10 761.77 -66.65 2.00 0.00 753.06 Start 20.00 hold at 2739.15 MD 7 2759.15 41.63 355.00 2568.05 775.01 -67.80 0.00 0.00 766.15 Start DLS 2.00 TFO 25.30 8 4449.81 73.33 9.38 3468.63 2174.28 17.67 2.00 25.30 2095.62 Start 4754.14 hold at 4449.81 MD 9 9203.95 73.33 9.38 4832.18 6667.85 759.63 0.00 0.00 6244.04 Start DLS 3.00 TFO -78.68 1010190.98 81.00 340.00 5055.93 7613.50 667.88 3.00 -78.68 7181.22 Start Build 2.00 11 10390.98 85.00 340.00 5080.30 7800.00 600.00 2.00 0.00 7378.93 Start 400.00 hold at 10390.98 MD 1210790.98 85.00 340.00 5115.16 8174.45 463.71 0.00 0.00 7775.89 Start DLS 2.00 TFO 78.16 1311041.23 86.04 344.91 5134.71 8412.25 388.54 2.00 78.16 8025.05 Start 486.77 hold at 11041.23 MD 1411528.00 86.04 344.91 5168.29 8881.12 262.11 0.00 0.00 8510.66 Start DLS 1.50 TFO 21.92 1511812.20 90.00 346.50 5178.10 9156.29 192.00 1.50 21.92 8794.60 3T-608 T02 Start DLS 1.50 TFO 29.53 1611851.76 90.52 346.79 5177.92 9194.78 182.87 1.50 29.53 8834.14 Start 5284.91 hold at 11851.76 MD 1717136.67 90.52 346.79 5130.30 14339.69 -1024.57 0.00 0.0014116.25 Start DLS 1.00 TFO -24.43 1817255.70 91.60 346.30 5128.10 14455.43 -1052.26 1.00 -24.4314235.22 3T-608 T03 Start DLS 1.00 TFO -36.08 1917349.52 92.36 345.75 5124.86 14546.41 -1074.90 1.00 -36.0814328.96 Start 1227.88 hold at 17349.52 MD 2018577.40 92.36 345.75 5074.34 15735.49 -1376.96 0.00 0.0015555.70 Start DLS 1.50 TFO 177.50 2118734.76 90.00 345.85 5071.10 15888.00 -1415.55 1.50 177.5015713.00 3T-608 T04 Start DLS 1.00 TFO 179.92 2218821.76 88.69 345.85 5072.09 15972.35 -1436.82 1.50 179.9215799.98 23 21191.90 88.69 345.85 5126.07 18270.00 -2016.00 0.00 0.0018169.24 TD at 21191.90 39 500 500 700 700 900 900 1300 1300 1600 1600 2000 2000 3000 3000 5000 5000 8000 8000 13000 13000 18000 18000 21192 3T-608 wp12 Plan Summary 0 3 Dogleg Severity0 3500 7000 10500 14000 17500 21000 Measured Depth 10-3/4" Surface Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 30 30 60 60 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in] 3950100150200250300350400450500 3T-605 wp05 v5 39501001502002503003504004505005516016517017518028529029521002 3T-606 wp06 v5 39501001502002503003504004505005506016517017518028529029531003105411051155120612571308135814091460 3T-607 wp05 v5 395010015020025030035040045050055060065070075080084989994999910491099114911991249129913491399 144914991549159916491699 1749179918491899194919992049209921492199 3T-609 wp06 v5 3950100150200250300350400450500550600650699749799849899949999104910991149 3T-610 wp05 v5 0 3250 True Vertical Depth0 2750 5500 8250 11000 13750 16500 Vertical Section at 345.00° 10-3/4" Surface Casing 7-5/8" Intermediate Casing 4-1/2" Production Liner 0 30 60 Centre to Centre Separation275 550 825 1100 1375 1650 1925 Measured Depth DDI 7.167 SURVEY PROGRAM Date: 2024-03-21T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.10 300.00 3T-608 wp12 (3T-608) INC 300.00 2680.00 3T-608 wp12 (3T-608) MWD+IFR2+SAG+MS 2680.00 9900.00 3T-608 wp12 (3T-608) MWD+IFR2+SAG+MS 9900.00 21191.90 3T-608 wp12 (3T-608) MWD+IFR2+SAG+MS Elevation / 12.00 CASING DETAILS TVD MD Name 2514.10 2687.38 10-3/4" Surface Casing 5005.10 9906.31 7-5/8" Intermediate Casing 5126.07 21191.90 4-1/2" Production Liner Mag Model & Date: BGGM2023 20-Sep-24 Magnetic North is 14.09° East of True North (Magnetic Declinat Mag Dip & Field Strength: 80.63° 57201.37nT FORMATION TOP DETAILS TVDPath Formation 1380.10 Top Ugnu C 1604.10 Top Ugnu B 1663.10 Base Permafrost 1702.10 Top Ugnu A 2004.10 Top West Sak 2493.10 Base West Sak 2548.10 C-80 2617.10 C-50 3764.10 C-35 4125.10 Top Coyote (Nanushuk), K3 4221.10 Base Coyote (Nanushuk) 5025.10 Top Torok (Moraine) By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by SLB DE Checked by SLB DEC Mgr Accepted by SLB PSD Approved by CoP DE Plan 12+39.1 @ 51.10usft (D142) -25000250050007500True Vertical Depth0 2500 5000 7500 10000 12500 15000 17500Vertical Section at 345.00°10-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner100020003000400050006000700080009000100001100012000 1300 0 14 000 15000 16000 17000 1800019000200002100021192 0°30°60°73°85°86°90°91° 92 °89°3T-608 wp12Top Ugnu CTop Ugnu BBase PermafrostTop Ugnu ATop West SakBase West SakC-80C-50C-35Top Coyote (Nanushuk), K3Base Coyote (Nanushuk)Top Torok (Moraine)3T-608 wp1210:25, May 10 2024Section View 035007000105001400017500South(-)/North(+)-14000 -10500 -7000 -3500 0 3500 7000 10500West(-)/East(+)3T-608 T05 0320243T-608 T023T-608 T033T-608 T043T-608 T01 04032410-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner50010001500200025003000350040004500500051263T-608 wp123T-608 wp12While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise.10:28, May 10 20243ODQ9LHZ $QQSQ}X !qmsQo 9wqeXT >cX IXii IXiiSqvX $X}c_o &%A jR~fR:urV "rprUr:adjjdt~ jR~fRhpUP/tRuf /tRuf<dYuEpdP /tRufA:RV A A A t 0qTQi!q qwWcoQX=XZXwXoTX BG$=X\XvXoTX 2$=X\XvXoTX 5qzb=XZXyoTX >|X!QiTiQcqo2XbqW MjjA :jRp ~]% :jRp ~]% AuY 3dpdnn"uRuY 9vqeXT/tRuf<dYuEpdP6r{a?jrtY jR~fREpdYV?RY~ 2Qs>}Xm *Xq$Qm 2QsNqoX >cX >cX9q}ccqo (vqm 9q}ccqoFoTXzQco IXii IXii9q}ccqo /tRufA:RV 3Rt ~] >iq=QWc} A 5 > ' I >}Xm$Qm 3YRp?YR1YYj E~dp`Mjj<Y[YuYpUY:rdp E~dp``YrVYdU~URjY[RUru dp 9q}ccqoFoTXzQco ~] ~] ~]*vqoW0XXi ~] IXiiSqy 2Q_oXcT} $X}c_o Wc5qX} Hx}cqo GXzcTQi>XTcqo A 2qWXi5QmX>QmsiX$QX ++3 A t 9bQ}X $Xsb(wqm-BG$ k}^ 9iQo>|XBqqi9vq_vQm$QX $Xsb(vqm$XsbBq }^l}^l>|X-IXiiSqvXl A tA A tA A tA A tA $XTicoQcqo $cs o_iX :1 6 5 k}^ BcX7o$Xsb ' I k}^ Bqqi5QmX=XmQvg} .6" .pUjdprnYYuDUrCYjYVud] 3L.)<? +3? 8K?+3L.)<?R` 3L.)<? +3? 8K?+3L.)<?R` 3L.)<? +3? 8K?+3L.)<?R` $cvXTcqo (cXiW>wXo_b ko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eparation Factor-1250 0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 15000 16250 17500 18750 20000 21250 22500Measured Depth (2500 usft/in)NDST-02/NDST-02PB13S-610/3S-6103S-617/3S-617ODST-47/ODST-473T-603/3T-603 wp09Plan: 3T-605 (05) Cantwell (I)/3T-605 wp05 v5Plan: 3T-607 (07) Childs (P)/3T-607 wp05 v5Plan: 3T-610 (10) Daisy (I)/3T-610 wp05 v5STOP DrillingTake Immediate ActionCaution - Monitor CloselyNormal OperationsProject: Kuparuk River Unit_2Site: Kuparuk 3T PadWell: 3T-608Wellbore: 3T-608Design: 3T-608 wp12 0 30 60 Centre to Centre Separation0 450 900 1350 1800 2250 Partial Measured Depth3T-605 wp05 v53T-606 wp06 v53T-607 wp05 v53T-609 wp06 v53T-610 wp05 v53T-608 wp12 Ladder View 0 150 300 Centre to Centre Separation0 3000 6000 9000 12000 15000 18000 21000 Measured DepthNDST-02NDST-02PB1ODST-473T-603 wp093T-601 wp05 v53T-602 wp05 v53T-604 wp05 v53T-605 wp05 v53T-606 wp06 v53T-607 wp05 v53T-609 wp06 v53T-610 wp05 v53T-611 wp06 v53T-612 wp08 v53T-613 wp05 v53T-614 wp05 v53T-615 wp05 v53T-616 wp05 v53T-617 wp05 v53T-618 wp05 v53T-619 wp06 v5SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.10 300.00 3T-608 wp12 (3T-608) INC 300.00 2680.00 3T-608 wp12 (3T-608) MWD+IFR2+SAG+MS 2680.00 9900.00 3T-608 wp12 (3T-608) MWD+IFR2+SAG+MS 9900.00 21191.90 3T-608 wp12 (3T-608) MWD+IFR2+SAG+MS 10:49, May 10 2024 CASING DETAILS TVD MD Name 2514.10 2687.38 10-3/4" Surface Casing 5005.10 9906.31 7-5/8" Intermediate Casing 5126.07 21191.90 4-1/2" Production Liner 39 500 500 700 700 900 900 1300 1300 1600 1600 2000 2000 3000 3000 5000 5000 8000 8000 13000 13000 18000 18000 21192 3T-608 wp12 TC View 30 30 60 60 90 90 120 120 150 150 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in] 18988 18944 18901 18857 18813 18769 18726 18682 18638 18593 18549 18505 ODST-47 3950100150200250300350400450500550601652702753804855906 958 1009 1060 3T-603 wp09 3950100150200250300350400450500551602653703754 3T-601 wp05 v5 3950100150200250300350400450500551 602652702753803 852 902 3T-602 wp05 v5 395010015020025030035040045050055160165270275380485490595610071057110811591209 3T-604 wp05 v5 3950100150200250300350400450500551601651702752803854904955100610561107115812081259 1310 1361 3T-605 wp05 v5 3950100150200250300350400450500551601651701751802852902952100210511101115112001249129813471396144514931542 3T-606 wp06 v5 395010015020025030035040045050055060165170175180285290295310031054110511551206125713081358140914601511156216131664171417641815186619171969202020712122217422252277232823802432248425362587264026922744279528482901 3T-607 wp05 v5 395010015020025030035040045050055060065070075080084989994999910491099114911991249129913491399 144914991549159916491699 1749179918491899194919992049209921492199224922992349239924502500255026002650 27002750 280028492898294729963044309331413189 3T-609 wp06 v5 3950100150200250300350400450500550600650699749799849899949999104910991149119912491299134914001450150015511601165117011751180118521902195320032054210421552206225623072358 3T-610 wp05 v5 395010015020025030035040045050055060064969974879784789694599410441093114211911240128813371386143414831531157916281677 3T-611 wp06 v5 3950100150200250300350400450500550 59964969874779784689594399210411089113811861234 3T-612 wp08 v5 395010015020025030035040045050055059964869874779684589494399210421090 113911881237 3T-613 wp05 v5 3950100150200250300350400450500549598 647 696 743 791 837 3T-614 wp05 v5 3950100150200250300350400450500549599648697745794843892 3T-615 wp05 v5 3950100150200250300350400 3T-616 wp05 v5 SURVEY PROGRAM Date: 2024-03-21T00:00:00 Validated: Yes Version: From To Tool 39.10 300.00 INC 300.00 2680.00 MWD+IFR2+SAG+MS 2680.00 9900.00 MWD+IFR2+SAG+MS 9900.00 21191.90 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 2514.10 2687.38 10-3/4" Surface Casing 5005.10 9906.31 7-5/8" Intermediate Casing 5126.07 21191.90 4-1/2" Production Liner SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 700.00 3.00 355.00 699.91 5.21 -0.46 1.50 355.00 5.16 Start Build 2.00 4 1637.02 21.74 355.00 1611.10 204.30 -17.87 2.00 0.00 201.96 Start 107.66 hold at 1637.02 MD 5 1744.68 21.74 355.00 1711.10 244.02 -21.35 0.00 0.00 241.23 Start Build 2.00 6 2739.15 41.63 355.00 2553.10 761.77 -66.65 2.00 0.00 753.06 Start 20.00 hold at 2739.15 MD 7 2759.15 41.63 355.00 2568.05 775.01 -67.80 0.00 0.00 766.15 Start DLS 2.00 TFO 25.30 8 4449.81 73.33 9.38 3468.63 2174.28 17.67 2.00 25.30 2095.62 Start 4754.14 hold at 4449.81 MD 9 9203.95 73.33 9.38 4832.18 6667.85 759.63 0.00 0.00 6244.04 Start DLS 3.00 TFO -78.68 1010190.98 81.00 340.00 5055.93 7613.50 667.88 3.00 -78.68 7181.22 Start Build 2.00 11 10390.98 85.00 340.00 5080.30 7800.00 600.00 2.00 0.00 7378.93 Start 400.00 hold at 10390.98 MD 1210790.98 85.00 340.00 5115.16 8174.45 463.71 0.00 0.00 7775.89 Start DLS 2.00 TFO 78.16 1311041.23 86.04 344.91 5134.71 8412.25 388.54 2.00 78.16 8025.05 Start 486.77 hold at 11041.23 MD 1411528.00 86.04 344.91 5168.29 8881.12 262.11 0.00 0.00 8510.66 Start DLS 1.50 TFO 21.92 1511812.20 90.00 346.50 5178.10 9156.29 192.00 1.50 21.92 8794.60 3T-608 T02 Start DLS 1.50 TFO 29.53 1611851.76 90.52 346.79 5177.92 9194.78 182.87 1.50 29.53 8834.14 Start 5284.91 hold at 11851.76 MD 1717136.67 90.52 346.79 5130.30 14339.69 -1024.57 0.00 0.0014116.25 Start DLS 1.00 TFO -24.43 1817255.70 91.60 346.30 5128.10 14455.43 -1052.26 1.00 -24.4314235.22 3T-608 T03 Start DLS 1.00 TFO -36.08 1917349.52 92.36 345.75 5124.86 14546.41 -1074.90 1.00 -36.0814328.96 Start 1227.88 hold at 17349.52 MD 2018577.40 92.36 345.75 5074.34 15735.49 -1376.96 0.00 0.0015555.70 Start DLS 1.50 TFO 177.50 21 18734.76 90.00 345.85 5071.10 15888.00 -1415.55 1.50 177.5015713.00 3T-608 T04 Start DLS 1.00 TFO 179.92 2218821.76 88.69 345.85 5072.09 15972.35 -1436.82 1.50 179.9215799.98 23 21191.90 88.69 345.85 5126.07 18270.00 -2016.00 0.00 0.0018169.24 TD at 21191.90 3T-608 wp12AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.10 300.00 INC300.00 2680.00 MWD+IFR2+SAG+MS2680.00 9900.00 MWD+IFR2+SAG+MS9900.00 21191.90 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName2514.102687.3810-3/4" Surface Casing5005.109906.317-5/8" Intermediate Casing5126.0721191.904-1/2" Production Liner1010202030304040505060600901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [20 usft/in]39501001502002503003504004505005516013T-605 wp05 v53950100150200250300350400450500551601651701751802852902952100210513T-606 wp06 v53950100150200250300350400450500550601651701751802852902953100310541105115512061257130813581409146015111562161316643T-607 wp05 v5395010015020025030035040045050055060065070075080084989994999910491099114911991249129913491399144914991549159916491699174917991849189919491999204920992149219922493T-609 wp06 v53950100150200250300350400450500550600650699749799849899949999104910991149119912493T-610 wp05 v539501001502002503003504004505005506006493T-611 wp06 v539 500500 700700 900900 13001300 16001600 20002000 30003000 50005000 80008000 1300013000 1800018000 21192From Colour To MD39.10 To 2700.00MD Azi TFace39.10 0.00 0.00500.00 0.00 0.00700.00 355.00 355.001637.02 355.00 0.001744.68 355.00 0.002739.15 355.00 0.002759.15 355.00 0.004449.81 9.38 25.309203.95 9.38 0.0010190.98 340.00 -78.6810390.98 340.00 0.0010790.98 340.00 0.0011041.23 344.91 78.1611528.00 344.91 0.0011812.20 346.50 21.9211851.76 346.79 29.5317136.67 346.79 0.0017255.70 346.30 -24.4317349.52 345.75 -36.0818577.40 345.75 0.0018734.76 345.85 177.5018821.76 345.85 179.9221191.90 345.85 0.00 3T-608 wp12AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.10 300.00 INC300.00 2680.00 MWD+IFR2+SAG+MS2680.00 9900.00 MWD+IFR2+SAG+MS9900.00 21191.90 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName2514.102687.3810-3/4" Surface Casing5005.109906.317-5/8" Intermediate Casing5126.0721191.904-1/2" Production Liner3030606090901201201501501801800901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]87398782882488658906894589849021NDST-02760576537701775077987847789579447992804180898137NDST-02PB12640269227442795284829012954300730603113316632203273332633804597464646954744479248414890493949885037508551343T-607 wp05 v526002650270027502800284928982947299630443093314131893237328533333T-609 wp06 v526113T-610 wp05 v539 500500 700700 900900 13001300 16001600 20002000 30003000 50005000 80008000 1300013000 1800018000 21192From Colour To MD2600.00 To 10000.00MD Azi TFace39.10 0.00 0.00500.00 0.00 0.00700.00 355.00 355.001637.02 355.00 0.001744.68 355.00 0.002739.15 355.00 0.002759.15 355.00 0.004449.81 9.38 25.309203.95 9.38 0.0010190.98 340.00 -78.6810390.98 340.00 0.0010790.98 340.00 0.0011041.23 344.91 78.1611528.00 344.91 0.0011812.20 346.50 21.9211851.76 346.79 29.5317136.67 346.79 0.0017255.70 346.30 -24.4317349.52 345.75 -36.0818577.40 345.75 0.0018734.76 345.85 177.5018821.76 345.85 179.9221191.90 345.85 0.00 3T-608 wp12AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.10 300.00 INC300.00 2680.00 MWD+IFR2+SAG+MS2680.00 9900.00 MWD+IFR2+SAG+MS9900.00 21191.90 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName2514.102687.3810-3/4" Surface Casing5005.109906.317-5/8" Intermediate Casing5126.0721191.904-1/2" Production Liner454590901351351801802252252702700901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [90 usft/in]19254192101916519121190771903218988189441890118857188131876918726186821863818593185491850518461184161837218327182821823718192ODST-4739 500500 700700 900900 13001300 16001600 20002000 30003000 50005000 80008000 1300013000 1800018000 21192From Colour To MD9900.00 To 21192.00MD Azi TFace39.10 0.00 0.00500.00 0.00 0.00700.00 355.00 355.001637.02 355.00 0.001744.68 355.00 0.002739.15 355.00 0.002759.15 355.00 0.004449.81 9.38 25.309203.95 9.38 0.0010190.98 340.00 -78.6810390.98 340.00 0.0010790.98 340.00 0.0011041.23 344.91 78.1611528.00 344.91 0.0011812.20 346.50 21.9211851.76 346.79 29.5317136.67 346.79 0.0017255.70 346.30 -24.4317349.52 345.75 -36.0818577.40 345.75 0.0018734.76 345.85 177.5018821.76 345.85 179.9221191.90 345.85 0.00 3T-608 wp12Spider Plot11:06, May 10 202439.10 To 21191.90Northing (6000 usft/in)Easting (6000 usft/in)404550556065Colville Delta 2404550NDST-02404550NDST-02PB14045503S-6104045503S-61740 45 50 5560ODSN-1740 45 50 5560ODSN-17L1404550ODST-474045503T-603 wp0940 4 5503T-601 wp05 v54 0 4 5503T-602 wp05 v54045503T-604 wp05 v54045503T-605 wp05 v54045503T-606 wp06 v54045503T-607 wp05 v54045503T-609 wp06 v54045503T-610 wp05 v54045503T-611 wp06 v54045503T-612 wp08 v54045503T-613 wp05 v5404550 3T-614 wp05 v54045 503T-615 wp05 v540 45503T-616 wp05 v54045503T-617 wp05 v54045 503T-618 wp05 v540453T-6214045503T-619 wp06 v5404 5 503T-620 wp05 v54045503T-622 wp05 v5404 5 503T-623 wp05 v54045503T-624 wp05 v54045503T-625 wp05 v54045 503T-626 wp05 v54045503T-627 wp05 v540 45 503T-628 wp05 v54045503T-629 wp05 v5403T-730 (I14) wp07403T-731 (P14) wp074045503T-608 wp12 3T-608 wp12Spider Plot11:09, May 10 202439.10 To 21191.90Northing (1500 usft/in)Easting (1500 usft/in)20253035404550NDST-0220253035404550NDST-02PB13S-6103S-617202530354045503T-603 wp0920 25 30 35 4 0 45 3T-601 wp05 v52 0 25 3 0 3 5 4 0 3T-602 wp05 v5202530354045503T-604 wp05 v5202530354045503T-605 wp05 v5202530354045503T-606 wp06 v5202530354045503T-607 wp05 v5202530354045503T-609 wp06 v5202530354045503T-610 wp05 v5202530354045503T-611 wp06 v5202530354045503T-612 wp08 v5202530354045503T-613 wp05 v5203T-614 wp05 v520253035404 5 503T-615 wp05 v5203T-616 wp05 v5202530354045503T-617 wp05 v520253035404 5 3T-618 wp05 v52025303540453T-621202530354045503T-619 wp06 v520253035404 53T-620 wp05 v5202530354045503T-622 wp05 v520253035403T-623 wp05 v52025303540453T-624 wp05 v5202530354045503T-625 wp05 v520253035403T-626 wp05 v5203T-627 wp05 v5202530 3 5 40 3T-628 wp05 v52025303540453T-629 wp05 v520253035403T-730 (I14) wp07202530 35403T-731 (P14) wp07202530354045503T-608 wp12 3T-608 wp12Spider Plot11:15, May 10 202439.10 To 21191.90Northing (450 usft/in)Easting (450 usft/in)2025NDST-022025NDST-02PB13S-6103S-6172025303T-603 wp0920 2 53T-601 wp05 v52 0 25 3T-602 wp05 v52025303T-604 wp05 v52025303T-605 wp05 v5202530353T-606 wp06 v52025303T-607 wp05 v5202530353T-609 wp06 v5202530353T-610 wp05 v52025303540453T-611 wp06 v52025303T-612 wp08 v52025303T-613 wp05 v53T-614 wp05 v520253T-615 wp05 v53T-616 wp05 v520253035403T-617 wp05 v520253T-618 wp05 v520253T-6212025303T-619 wp06 v520253T-620 wp05 v52025303T-622 wp05 v520253T-623 wp05 v520253T-624 wp05 v520253T-625 wp05 v520253T-626 wp05 v520253T-628 wp05 v53T-629 wp05 v5202530353T-730 (I14) wp07202530 353T-731 (P14) wp07202530353T-608 wp12 3T-608 wp12Spider Plot11:19, May 10 202439.10 To 21191.90Northing (150 usft/in)Easting (150 usft/in)12141618NDST-0212141618NDST-02PB124681012141618203T-603 wp0924681012141618 20 2 2 3T-601 wp05 v5246 8 10 12 1 4 16 18 2 0 3T-602 wp05 v52468101214161820223T-604 wp05 v52468101214161820223T-605 wp05 v5246810121416182022243T-606 wp06 v5246810121416182022243T-607 wp05 v524681012141618202224263T-609 wp06 v5246810121416182022243T-610 wp05 v524681012141618202224263T-611 wp06 v52468101214161820223T-612 wp08 v52468101214161820223T-613 wp05 v52468103T-614 wp05 v524681012141618203T-615 wp05 v524683T-616 wp05 v524681012141618203T-617 wp05 v5246810121416183T-618 wp05 v51012143T-621810121416183T-619 wp06 v5101214163T-620 wp05 v514163T-622 wp05 v5143T-623 wp05 v51224 2628 303234363T-731 (P14) wp0724681012141618202224263T-608 wp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"&3 N N N N N N #!%((N 3T-608 wp12Colville Delta 2NDST-02NDST-02PB13S-6103S-617ODSN-17ODSN-17L1ODST-473T-603 wp093T-601 wp05 v53T-602 wp05 v53T-604 wp05 v53T-605 wp05 v53T-606 wp06 v53T-607 wp05 v53T-609 wp06 v53T-610 wp05 v53T-611 wp06 v53T-614 wp05 v53T-616 wp05 v53T-617 wp05 v53T-6213T-624 wp3T-628 wp05 v3T-629 wp05 3-D View3T-608 wp1212:07, May 10 2024 3T-608 wp12Colville Delta 2NDST-02NDST-02PB13S-6103S-617ODSN-17ODSN-17L1ODST-473T-603 wp093T-601 wp05 v53T-602 wp05 v53T-604 wp05 v53T-605 wp05 v53T-606 wp06 v53T-607 wp05 v53T-609 wp06 v53T-610 wp05 v53T-611 wp06 v53T-612 wp08 v53T-613 wp05 v53T-616 wp05 v53T-617 wp05 v53T-619 wp06 v53T-622 wp05 v53T-625 wp05 v53-D View3T-608 wp1212:07, May 10 2024 3T-608 wp12Colville Delta 2NDST-02NDST-02PB13S-6103S-617ODSN-17ODSN-17L1ODST-473T-603 wp093T-601 wp05 v53T-602 wp05 v53T-604 wp05 v53T-605 wp05 v53T-606 wp06 v53T-607 wp05 v53T-609 wp06 v53T-610 wp05 v53T-611 wp06 v53T-612 wp08 v53T-613 wp05 v53T-616 wp05 v53T-617 wp05 v53T-619 wp06 v53T-622 wp05 v53-D View3T-608 wp1212:08, May 10 2024 3T-608 wp12Colville Delta 2NDST-02NDST-02PB13S-6103S-617ODSN-17ODSN-17L1ODST-473T-603 wp093T-601 wp05 v53T-602 wp05 v53T-604 wp05 v53T-605 wp05 v53T-606 wp06 v53T-607 wp05 v53T-609 wp06 v53T-610 wp05 v53T-611 wp06 v53T-614 wp05 v53T-615 wp05 v53T-616 wp05 v53T-617 wp05 v53T-618 wp05 v53T-6213T-620 wp05 v53T-623 wp05 v53T-626 wp05 v53T-730 (I14) wp073T-731 (P14) wp073-D View3T-608 wp1212:08, May 10 2024 6000900012000150001800021000South(-)/North(+) (3000 usft/in)-12000 -9000 -6000 -3000 0 3000 6000 9000 12000West(-)/East(+) (3000 usft/in)5000505051005150Colville Delta 25000505051005150NDST-025000505051005150NDST-02PB13S-6103S-617ODSN-17ODSN-17L15000505051005150ODST-4750005050510051503T-603 wp0950005050510051503T-601 wp05 v5510051503T-602 wp05 v550005050510051503T-604 wp05 v550005050510051503T-605 wp05 v550005050510051503T-606 wp06 v550005050510051503T-607 wp05 v550005050510051503T-609 wp06 v550005050510051503T-610 wp05 v551503T-611 wp06 v551503T-612 wp08 v550005050510051503T-613 wp05 v53T-614 wp05 v55000505051003T-615 wp05 v53T-616 wp05 v53T-617 wp05 v53T-618 wp05 v550005050510051503T-619 wp06 v551503T-622 wp05 v53T-624 wp05 v53T-625 wp05 v53T-629 wp05 v550005050510051503T-608 wp123T-608 wp12Quarter Mile View11:55, May 10 2024WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T-608 T02 5178.10 Circle (Radius: 100.00)3T-608 T03 5128.10 Circle (Radius: 100.00)3T-608 T04 5071.10 Circle (Radius: 100.00)3T-608 T01 040324 5032.10 Circle (Radius: 100.00)3T-608 T01 QM 5032.10 Circle (Radius: 1350.00)3T-608 T02 QM 5178.10 Circle (Radius: 1350.00)3T-608 T03 QM 5128.10 Circle (Radius: 1350.00)3T-608 T05 032024 5126.07 Circle (Radius: 100.00)3T-608 T05 QM 5126.07 Circle (Radius: 1350.00) 6000900012000150001800021000South(-)/North(+) (3000 usft/in)-12000 -9000 -6000 -3000 0 3000 6000 9000 12000West(-)/East(+) (3000 usft/in)5000505051005150Colville Delta 25000505051005150NDST-025000505051005150NDST-02PB13S-6105000505051005150ODST-4750005050510051503T-603 wp093T-617 wp05 v550005050510051503T-608 wp123T-608 wp12Quarter Mile View12:01, May 10 2024WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T-608 T02 5178.10 Circle (Radius: 100.00)3T-608 T03 5128.10 Circle (Radius: 100.00)3T-608 T04 5071.10 Circle (Radius: 100.00)3T-608 T01 040324 5032.10 Circle (Radius: 100.00)3T-608 T01 QM 5032.10 Circle (Radius: 1350.00)3T-608 T02 QM 5178.10 Circle (Radius: 1350.00)3T-608 T03 QM 5128.10 Circle (Radius: 1350.00)3T-608 T05 032024 5126.07 Circle (Radius: 100.00)3T-608 T05 QM 5126.07 Circle (Radius: 1350.00) 025050075010001250South(-)/North(+) (250 usft/in)-1000 -750 -500 -250 0 250 500 750 1000West(-)/East(+) (250 usft/in)NDST-02NDST-02PB1250025203T-603 wp093T-601 wp05 v53T-602 wp05 v5250025203T-604 wp05 v5250025203T-605 wp05 v5250025203T-606 wp06 v5250025203T-607 wp05 v5250025203T-609 wp06 v5250025203T-610 wp05 v5250025203T-611 wp06 v5250025203T-612 wp08 v5250025203T-613 wp05 v5250025203T-615 wp05 v5250025203T-617 wp05 v5250025203T-618 wp05 v53T -6 2 125002520 3T-619 wp06 v53T-620 wp05 v5250025203T-622 wp05 v53T-623 wp05 v53T-624 wp05 v53T-625 wp05 v5250025203T-730 (I14) wp072 5 002520 3T-731 (P14) wp0710-3/4" Surface Casing250025203T-608 wp123T-608 wp12Surface Casing 500 ft r12:38, May 10 2024WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T-608 T02 5178.10 Circle (Radius: 100.00)3T-608 T03 5128.10 Circle (Radius: 100.00)3T-608 T04 5071.10 Circle (Radius: 100.00)3T-608 Srf Csg 2514.10 Circle (Radius: 500.00)3T-608 T01 040324 5032.10 Circle (Radius: 100.00)3T-608 T01 QM 5032.10 Circle (Radius: 1350.00)3T-608 T02 QM 5178.10 Circle (Radius: 1350.00)3T-608 T03 QM5128.10Circle (Radius: 1350.00)3T-608 T05 032024 5126.07 Circle (Radius: 100.00)3T-608 T05 QM 5126.07 Circle (Radius: 1350.00) 025050075010001250South(-)/North(+) (250 usft/in)-1000 -750 -500 -250 0 250 500 750 1000West(-)/East(+) (250 usft/in)250025203T-607 wp05 v5250025203T-609 wp06 v5250025203T-610 wp05 v5250025203T-611 wp06 v510-3/4" Surface Casing250025203T-608 wp123T-608 wp12Surface Casing 500 ft r12:38, May 10 2024WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3T-608 T02 5178.10 Circle (Radius: 100.00)3T-608 T03 5128.10 Circle (Radius: 100.00)3T-608 T04 5071.10 Circle (Radius: 100.00)3T-608 Srf Csg 2514.10 Circle (Radius: 500.00)3T-608 T01 040324 5032.10 Circle (Radius: 100.00)3T-608 T01 QM 5032.10 Circle (Radius: 1350.00)3T-608 T02 QM 5178.10 Circle (Radius: 1350.00)3T-608 T03 QM5128.10Circle (Radius: 1350.00)3T-608 T05 032024 5126.07 Circle (Radius: 100.00)3T-608 T05 QM 5126.07 Circle (Radius: 1350.00) 3T-608wp12 Surface Location 3T-608wp12 Surface Location # Schlumberger-Confidential 3T-608wp12 Surface Casing 3T-608wp12 Surface Casing # Schlumberger-Confidential 3T-608wp12 Intermediate Csg 3T-608wp12 Intermediate Csg # Schlumberger-Confidential 3T-608wp12 Top Torok (Moraine) 3T-608wp12 Top Torok (Moraine) # Schlumberger-Confidential 3T-608wp12 TD 3T-608wp12 TD # Schlumberger-Confidential 1 Dewhurst, Andrew D (OGC) From:Broussard, Brian T <Brian.T.Broussard@conocophillips.com> Sent:Monday, 22 July, 2024 09:24 To:Dewhurst, Andrew D (OGC) Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Loepp, Victoria T (OGC); Roby, David S (OGC) Subject:RE: [EXTERNAL]KRU 3T-608 PTD (224-094): Questions Attachments:3T-608 Area of Review_V2.pdf Follow Up Flag:Follow up Flag Status:Flagged Hi Andrew, Please see answers in the original email. Thanks, Brian Broussard Drilling Engineer – Kuparuk 700 G Street, Anchorage, AK 99501 Cell: 337.967.0516 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Friday, July 19, 2024 4:00 PM To: Broussard, Brian T <Brian.T.Broussard@conocophillips.com> Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]KRU 3T-608 PTD (224-094): Questions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Brian, I am reviewing the KRU 3T-608 PTD (224-094) and have a few quesƟons: x Would you conĮrm that the X/Y coordinates on the 10-401 and SecƟon 2 LocaƟon Summary are swapped. If so, I can correct. o I have conƱrmed that the coordinates were swapped. Apologies for the error. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 x Are you planning on pre-producing this well before injecƟon? o We are not planning to pre-produce this well x Regarding the Area of Review, would you double-check to see if the KRU 3S-617 well path encroaches into the quarter-mile radius? If so, please provide an updated AOR PDF. o The 3S-617 was missed while the permit pack was being assembled. Apologies for the error. I have updated the AOR document and attached it to this email. Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 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 nogreater 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. KRU 3T-608 224-094 KUPARUK RIVER TOROK OIL WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 3T-608Initial Class/TypeSER / PENDGeoArea890Unit11160On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2240940KUPARUK RIVER, TOROK OIL - 490169NA1Permit fee attachedYesADL025528 and ADL3938832Lease number appropriateYes3Unique well name and numberYesKUPARUK RIVER, TOROK OIL - 490169 - governed by CO 725A4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitYesAIO 39A14Well 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)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes81' driven conductor18Conductor string providedYesSC set at 2686' MD19Surface casing protects all known USDWsYes214% excess cement planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoProductive interval will be completed with uncemented liner with frac sleeves and swell packers22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedYes27If diverter required, does it meet regulationsYesMax formation pressure is 2316 psig(8.8 ppg EMW); will drill w/ 9.0-9.5 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 1798 psig; will test BOPs to 5000 psig initially and 4000 psig subsequently30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYes33Is presence of H2S gas probableYes34Mechanical condition of wells within AOR verified (For service well only)NoMeasures required. 70 ppm recorded at adjacent 3S-610 (2024)35Permit can be issued w/o hydrogen sulfide measuresYesAnticipated pore pressure for Moraine and Coyote is 8.6 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]ApprADDDate7/22/2024ApprVTLDate7/15/2024ApprADDDate7/22/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 8/13/2024
