How can you optimize the performance of a progressive cavity pump?

Optimizing the performance of PCPs involves various design, operational, and maintenance practices such as: 1. Proper pump selection: Ensure the PCP is appropriately sized taking into account the fluid properties, flow rate requirements, and system pressure conditions. 2. Speed control: Adjust the speed of the PCP to match the required flow rate. Slower speeds can extend the pump's life and reduce wear. 3. Monitoring and control: Real-time data helps detect issues early. 4. Fluid conditioning: Consider using filters or separators to remove solids and abrasives. 5. Correct piping design: Proper piping design helps minimize pressure losses, cavitation, and other inefficiencies.

In my experience multiphase flow and production of solids within the pumped fluids were the most critical causes of pump wear and failures. Therefore these two topics would be investigated as aspects of pump design that most affect the ability of the pump to produce solids.

Only one example , We can optimize a BCP , using a VSP , of course collect the most quantitive of inputs for design , such us type of oil , gas , water , solids , etc. If we have a field under waterflooding , material balance , etc.

it is instrumental to know utilization in terms what have been pumped through them and use data to get the big picture. Predictive maintenance and Beyond.

1.Thermal Management - Implement measures to manage heat generated during pump operation. Excessive heat degrades pump performance & reduce overall efficiency. 2.Optimized Pump Curves - Understand & optimize the pump curves, ensuring that the pump operates within its designated range for maximum efficiency. 3. Efficient Motors - Ensure the pump is equipped with an energy-efficient motor to reduce overall power consumption and operating costs. 4. Monitoring & Controlling Systems - Employ monitoring systems to track pump performance & detect anomalies early. Incorporate control systems that can automatically adjust pump settings based on real-time conditions. 5.Seal Selection - Use high-quality seals to reduce leakage & maintain efficiency.

You need to consider using InflataLOK from IPI Packers. A revolutionary product that combines an hydraulically set inflatable seal and mechanical slips. This unique design provides superior flexibility for the installation of Insert Progressive Capacity Pumps (I-PCP). InflataLOK from is a Nipple-less Insert-PCP anchor system. This means it does not require a J-Slot for PCP pump installation. This feature further simplifies the installation process, reducing the time and effort required. By eliminating the need for a J-Slot, It also reduces the potential for mechanical failures, enhancing the reliability and efficiency of the PCP system. This makes InflataLOK an even more valuable tool in optimizing the efficiency of PCP pump installations.

Well deviation can substantially impact PCP operations due to increased drag and torque forces acting on the rod string. Highly deviated sections and tight bends lead to more friction against the tubing wall, which reduces the available weight for the PCP to pull on for lifting. Severe cases can differentially stick the rods or lead to premature failure through fatigue or buckling. As a rule of thumb, I prefer not to run PCP’s in wells with deviations above 10o/30m or at best, hang off above sections of increased deviation. This allows for continued production without rod sticking even in cases of extreme elastomer swell, or solids production

Me ha resultado útil, ya que en mi experiencia acá en Venezuela hay muchos dise?os improvisados por falta de algunos materiales u herramientas, los cuales no siguiendo estos pasos en las instalaciones tienen como consecuencia fallas prematuras en los sistemas PCP, y se?alan como causante de falla siempre a la bomba PCP y no al mal dise?o del sistema en general.

It may seem to everyone like the smallest link in the chain in a PCP system, but the correct installation of the pump requires correct make-up practice of the sucker rods during the pulling operation, as well as the correct selection of the material of the suckers. sucker rods (considering the corrosive environment, wellbore deviation, maximum torque capacity to be transmitted, etc.)

También podría colocarse la bomba debajo de los perforados, teniendo mejor sumergencia, eso si, asegurando que la tubería que quede enfrentando a los perforados sea resistente (blast joint).

In operations, the optimal way to operate an artificial lift system is often contrasted with the specific need to produce oil and gas, or with the companies' extractive policy. For a PCP system to operate efficiently, the optimal operating range of the pump (flow rate, rotation speed) must be taken into account and adequately protected through the use of VFD's and downhole sensors that allow to adjust the regime extraction.

Torque is an important parameter to watch during PCP run. A robust surveillance algorithm providing the real time capibility to adjust the speeds based upon torque trends creates an opportunity to optimise pump condition and it's runlife.

Device such as an automatic control valve for casing pressure has worked reducing water cut of the well and pump efficiency,

Optimizing progressive cavity pump performance requires proper pump selection based on flow rate, head, and fluid properties; correct installation aligned with tubing and centered in the casing; efficient operation at optimal RPM with controlled discharge pressure and minimal gas interference; and regular maintenance through inspections, prompt replacement of worn components, adequate lubrication, fluid quality monitoring, and following manufacturer guidelines. Implementing these best practices for sizing, installing, operating, and maintaining progressive cavity pumps allows for maximum efficiency, reduced wear, and prevention of failures or production losses.

Carlos, I like that. Increase CHP to avoid gas intake at pump is great, but ultimately, we want to get fbhp down. I would like to do experiments cycling through pumping down well while csg shut in, followed by stop the pump and open annulus. That sequence could be automated of course, but the sweet spot needs review.

I've found that a combined approach to sand management is the best way to tackle this issue. During well construction in a very low consolidated formation, using a wire wrapped sand screen in tandem with a downhole desander, for example, hung off on the base of the PCP string can be really effective; especially if the formation sand is large enough to pack off around the screens without severely impeding fluid flow.

PM plan to be generated and that should be followed so that none of the pump missed from the list. The dashboard could be developed that show flow and discharge pressure of the pump continuously monitored.

Avoid PCP running dry even momentarily Elastomer stators to be protected and maintained Avoid fluid high temperature of >100 C

Sin duda la pericia de campo, los a?os de experiencia de profesionales apasionados por la industria, y el trabajo en equipo de varias empresas en pro de culminar un pozo exitosamente. Así como lo dijo el estimado anteriormente, no sería posible. El trabajo en conjunto de la parte ingenieril como técnica, la comunicación efectiva y las mesas de trabajo previa a las operaciones.