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But after a couple of weeks, the well is tested and detect that the water cut has change from 20 % to 65 %, so It has been a waste of time and money. Anyway, a new downhole assembly is installed with a bigger pump capacity, and with the new pump a production increase is expected. Base on the PIP and surface operational parameters is determinate that there is an opportunity to increase production, but due to problems with the Test Separator and the Laboratory, there isn’t water cut information’s. Take in considerations that a water outbreak could occur in days if the Artificial Lift System is operated inappropriate and excessive draw down (Reservoir – Bottom hole) is created.Įvaluate this case. Why? Because, any optimizing proposal or even workover couldn’t be worthy if you are producing a lot of water.
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When you don’t have the enough test facilities at the pump station (too many wells) to evaluate the wells frequently (at least twice a month), would be very useful to determine water cut through surface samples, or even the subjective visual appreciation by the field crew of the amount of water produced. Base on the evaluation of practices apply by different Companies (Operator) our recommendation is to test the well at least twice a month even better, if an on-line flow meter could be installing would be very useful. But, normally there are operations issue or a Production Test is rejected due to some parameters don’t agree with the tendency and could be a long period (two months or more) without the Well Production Information, and during this period many parameters could change a lot, affecting the Well performance. The surface facility is design to measure the Well production as much as possible. The Flow rate calculate with the IPR (PIP, Ps, Ql well test) compared with the pump’s theoretical output capacity can suggest the condition and actual performance of the pumping system.įlow Rate Vs Q theo = 5.94x10 -1 * e*D*p*N The PIP (sensor / Liquid level) could be used for more than an alarm, this is a referent of the reservoir energy, and the reservoir Inflow (IPR) can be calculate combining PIP, a production test and the static pressure. Unlike pressure, the torque is related with mechanical components of the system, and the PIP with the reservoir energy. Monitoring this parameter allow to detect wear pump, elastomer swell, sands plugs, production of gas, etc. The same things could be done for the TORQUE. Or compare the PIP with the average of the PIP value in the last 15 days if there wasn’t any major event (Assuming the same pump, no change in RPM, no chemical treatment, among others).
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In these cases, is really important to discretize the information, and carefully design reports generated by the SCADA that highlight the most important evens.ĭifferent Views/Alarm can be configured in your SCADA software An alarm LOW/HIGH PIP that compare the PIP value whit a previous establish set point.
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But at the same time the optimization engineer would be full of information, alarm, trend curves. Is a fact that the “Automation” will contribute to your job. All the settings (High Torque, PIP, CHP, THP, RPM ….) required by the “Pump Controller” and SCADA must be defined by the Productions Engineer and work together with the AIT department to achieve the configuration and integration (Monitoring and Remote Control) between the automation devices and the SDACA.
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With the Automation advantage the Oil Production can be maximized by improving uptime through pump protection settings, control devices, and control modes (algorithms). In fact, Automation with appropriate parameters and algorithms can perform routine adjustments with minimal supervision, which provides an opportunity to focus on atypical cases, failure analysis, among others. Therefore, there is available a powerful tool “Automation” The advantages offered by the immediacy, high frequency and accurate information received by telemetry are indisputable. Thus, is almost impossible to monitoring and evaluate in deep all of them. For each one, tools/methodologies to improve the oil production or equipment protection are explained.Īn Optimization Engineer could analyze in detail between 06 to 08 wells per day, but normally is responsible for 80 – 120 wells. This note is focus in Monitoring the Progressive Cavity Pumps from two point of view, one as an Optimization Engineer and the other as a File Crew Personal.