Schneider Electric Systems USA, Inc.

Schneider Electric Systems Canada Inc.

James Redmond

Zackery Sobin

Scott Guimond

Stephen Neave

System/method for real-time monitoring and control of pump operations at a well provide a pump control system that uses pump fillage with a proportional-integral-differential (PID) based algorithm to control positive displacement pump operations. The pump control system/method obtains measured or inferred pump speed from available pump speed data and, using certain pump characteristics provided by the well operator, calculates a theoretical fluid flow rate based on the pump speed. The pump control system/method thereafter compares the calculated theoretical fluid flow rate to a measured or observed fluid flow rate to calculate a pump fillage. The calculated pump fillage is then provided as a process input to the PID based algorithm along with a desired pump fillage from the well operator. The PID based algorithm processes the calculated pump fillage and the desired pump fillage using tuning parameters to determine an optimum pump speed based on the desired pump fillage.

Progressing cavity pump control using pump fillage with PID based controller

Remote configuration of an industrial or remote telemetry device using sound. Acoustic energy directed from a remote programming device to a remote industrial or telemetry device has tones indicating a request to establish communication. By directing further acoustic energy from the remote programming device to the remote industrial or telemetry device, the remote programming device requests information relating to a current configuration of the remote industrial or telemetry device. The remote industrial or telemetry device processes the tones to identify the request and replies with acoustic energy that has associated tones indicating the information relating to the current configuration of the remote industrial or telemetry device.

Acoustic node for configuring remote device

Centrally optimizing production of a reservoir that has a plurality of wells comprises monitoring production of each well in the reservoir using one or more respective sensors at each well. Sensor data indicative of the monitored production of each well from the one or more respective sensors is input to a central processing device for processing to evaluate the production of each well. The production of each well is evaluated to identify opportunities for optimizing production by the plurality of wells in the reservoir. In addition, one or more actions are taken using the central processing device to optimize production by the plurality of wells based on the identified opportunities for optimizing production.

Systems and methods for centralized optimization of reservoir production

Systems and methods for providing power to devices at a well site employ a linear alternator to generate power at a well site. The linear alternator is mounted on a pump at the well site and uses the up-and-down motion of the pump to generate power. The pump may be a nodding donkey head pump or other sucker rod pump mechanisms that operate based on linear vertical motion. The linear vertical motion drives a linear rotor back and forth through a linear stator to induce current in the linear alternator. This allows the linear alternator to convert a portion of the mechanical work performed by the pump into electrical energy that can be supplied to the devices. In some embodiments, the pump-mounted linear alternator can be equipped with a position sensor to directly measure a vertical position of the pump as the alternator travels up and down with the pump.

Pumpjack having linear alternator

A load cell system for measuring rod load in a pumpjack. The system includes a tension load cell operatively coupled to a bridle between first and second bridle cables at a location longitudinally spaced between a horsehead and a bridle plate of the pumpjack. The bridle plate is coupled to the first bridle cable at a first connection point and the tension load cell is coupled to the first bridle cable at a second connection point longitudinally spaced between the bridle plate and the horsehead. The load cell system defines a third connection point longitudinally spaced between the second connection point and the horsehead. The load cell system is configured to maintain substantially constant longitudinal distances between the second connection point and each of the first and third connection points during operation of the horsehead. The load cell system is further configured to maintain a substantially constant lateral distance between the first and second bridle cables at the third connection point during operation of the horsehead.

Load cell system for pumpjack and method of installing load cell

Systems and methods provide real-time optical monitoring and control of well operations using digital cameras and image analysis. The systems and methods deploy one or more digital cameras in place of or in addition to conventional sensors to capture images of a well pump during well operations. The images may then be analyzed using image analysis algorithms and programs to measure a height, position, shape, and other measurements for certain components of the well pump relative to previous images. These image-based measurements may then be used to determine various operational parameters, such as pump speed, pump load, and other operational parameters. The operational parameters may then be processed by a pump control system to optimize pump operations based on the operational parameters.

Optical monitoring and control of pumpjack

A method and system for determining the pump fillage of a sucker rod pumping system using torque feedback when pumping wellbore fluids from the particular well on which the sucker rod pumping system is installed. During the pump stroke, a microprocessor samples torque of the pump's mechanical system at an associated horsehead position at regular intervals and once the stroke is completed the raw torque samples and associated horsehead positions are placed in an array, the array of raw torque samples and horsehead positions can be filtered by the microprocessor into a second filtered array and then converted by the microprocessor into a rotatum array (derivative of torque with respect to time) of one or both of the raw or filtered arrays and stored as a rotatum array. The down stroke portion of the rotatum array is then analyzed by the microprocessor to determine the horsehead position when the piston of the down hole pump encounters wellbore fluid in the well (pump fillage). The microprocessor, based on the determined pump fillage, adjusts the speed of the pumping system to maintain an optimal pump fillage determined to be the most economical for the particular well on which the sucker rod pumping system is installed.

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Richmond, CA, United States of America

James Redmond