The Proportional, Integral, Derivative (PID) control algorithm has been used in industry for many years. The proper application and tuning of this algorithm has been the topic of much research and many papers. Its use with ESPs has been underutilized, yet its benefit is significant when employed properly for many reasons. Monitoring and benchmarking the system's performance while in PID mode can be hap-hazard unless employing a remote monitoring system that provides visibility for tuning and optimizing of the control algorithm. This paper looks at two ESP systems where operation was benchmarked before the PID algorithm was implemented. The operation was then compared after the PID control mode was implemented with the aid of a downhole gauge unit. The resulting effect on the pumping system was then quantified through the use of remote monitoring and analysis systems. Significant benefits in the pumping system were shown, such as increased run life (from cooler operation), lower operating temperatures in the ESP motor, lower operating frequency resulting in lower power consumption, and stable downhole pressures with the ability to manage free gas during operation. Production and efficiency gains were realized through increased drawdown, stable operation, and immediate feedback from key operational information. Finally, the importance of proper tuning of the control algorithm is critical for the success of the implementation.
Unfortunately, most of today's oil and gas fields are not located in our backyard, or in easily accessible locations for that matter. The "easy oil," as many call it, is long gone so now we are forced to explore new frontiers, from ultradeepwater areas, to the Arctic Circle, deserts, or deep inside tropical jungles. These remote and inhospitable environments present a series of logistical challenges to oilfield operators. Accessing these areas, establishing the necessary infrastructure, and mobilizing personnel and equipment required to operate an oil field can be costly, risky, and time-consuming. On the other hand, in today's modern business world, technology is employed on a daily basis to overcome geographical boundaries or obstacles and make us more efficient. Thanks to telecommuting, millions of workers do not have to drive to the office: the office comes to them. Thanks to collaboration through virtual teams, individuals do not need to work in the same physical space nor meet face to face to be able to accomplish tasks; which saves millions of dollars in cost and time associated with business travel. This paper presents a series of case histories demonstrating how intelligent completion and production systems can be used to apply the same telecommuting and virtual team concepts to solve some of the logistical challenges faced in today's remote oilfield operations. An outline of general considerations and recommendations is also proposed as a guide for individuals planning to implement these technologies.
This paper will outline the corporate culture and environment that affected how a service company engaged the digital oil field (DOF) concept and continues to embrace it moving forward. We will discuss how the company continues to address the need for a digital energy/digital oil field initiative not only for its customers, but for its own use as well. Discussion will cover topics from early individualized products to meet exploration and production (E&P) customers' needs through maturation of those products. We'll describe the bundling and eventual integration of those products into a system—integrated with human resources—to address the needs of a modern exploration, drilling, completion and production scenario. The response to the myriad issues with hardware to produce data, software to manage data, and ultimately the workflow and culture around using information is an evolutionary process. Missteps and successes brought on by that evolution should be noted as lessons learned, which can be applied by others to move forward with their own DOF technology.
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