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DocuSign Envelope ID:6BC32598-B737-464E-898A-81 F1 F7131339133 <br /> Attachment D. Injection Operation and Monitoring Program <br /> Exhibit D-1 is a schematic overview of the anticipated surface equipment and layout. Seep water <br /> will be stored in a small tank battery prior to injection. Water will be pulled from the tank battery <br /> and delivered to a fit for purpose displacement pump. Table D-1 presents an overview of key <br /> system components. <br /> Table D-1. Overview of Key System Components <br /> Item Capacity or Operating Condition Location <br /> Storage Tanks At least 500 bbl. Near seep <br /> Centrifugal Pump 3-20 bpm, 0-200 psi Near seep <br /> Transfer Line, Likely HPPE 0-10 bpm, 0-500 psi Between storage battery and wellsite <br /> Surge Tank Possibly 300 bbls Wellsite <br /> Biocide storage tank and pump Sufficient to treat up to 10 bmp Wellsite <br /> Centrifugal Pump 3-10 bpm, 0-200 psi Wellsite <br /> Positive Displacement Injection 3-10 bpm, (operating pressure <br /> Pump determined post SRT) Wellsite <br /> Injection Tubing 0-10 bpm Well <br /> Injection Packer 0-10 bpm Well <br /> The well and associated equipment will be sized to handle the largest anticipated injection <br /> rates (-300 gpm or—10,000 bpd). The pump operation will be regulated by a level sensor in the <br /> surge tank and the pump rate reduced or shut down corresponding to the rate of seepage <br /> collection. All facilities will be inspected by mine personnel on a regular basis to ensure proper <br /> working conditions and prevent uncontrolled releases. In case of an emergency, automated <br /> SCADA telemetry alarms will notify operator personnel. <br /> A fitting and valve assembly between the storage battery and the injection wellhead will permit <br /> sampling of the injection fluid. Additionally, there will be monitoring equipment tie-ins for real <br /> time monitoring of injection tubing and casing pressure and injection rate readings at the <br /> wellhead. <br /> Average projected injection rates are anticipated to be on the order of 160 gpm varying seasonally <br /> up to 300 gpm. <br /> Surface injection pressures will be kept below the receiving formation fracture pressure. The <br /> maximum operational pressure will be determined based on the SRT results. <br /> Well Failures <br /> Table D-2 lists the most likely causes for well failure. <br /> 12 <br />