Trending Content

Smart Production Monitoring Enabled by Virtual Well Metering

Add to Cart
Course Credit: 0.1 CEU, 1 PDH

Virtual Metering technology has been used in offshore oil and gas wells for over a decade with great success. They provide a cost-effective, yet reliable solution to monitor production continuously. They also serve as ready back-up to “physical” multiphase meters, which are both expensive and less reliable.

On one asset that has been producing for over 18 years, Virtual Metering enabled reliable production metering, where it was previously not possible to do any type of well testing. In this case, the production metering process was successful because the Virtual Metering utilized multiple methods to predict flowrates and was able to keep predicting accurate flowrates, even as various pressure/temperature measurements / sensors in and around the wells failed over time.

Another key component to the successful implementation of virtual meters is to leverage all data, including export meters, to calibrate the system. However, calibration presents unique challenges, especially in situations in which multiple wells are commingled and measured at a common meter. Recent advances in Data Analytics present a great opportunity to simplify the complex calibration challenge. On a recent project, several of the physical subsea multiphase meters were not performing reliably, and the back-up virtual meters required a higher level of accuracy (i.e., >99%), as these meters were used for allocation purposes. With only one export meter available as a point of calibration, Data Analytics was used to automate the complex calibration process that led to more than an 80% reduction in calibration times. These developments and advanced in the technology has allowed the Virtual Metering software to be scalable for application on vast networks such as shale well and coal seam gas, in addition to conventional producing assets.

Lastly, Virtual Metering technology has proven to be an excellent backup to full multiphase meters on each well. Because Virtual Metering facilitates improved visualization of the whole field’s production performance, the users can determine if there are any biases in each individual multiphase meters and actually helps improve the accuracy of these “physical meters”.

Post Tags

 1 chapter
  1 downloadable resource

Course Chapters

  • 1Smart Production Monitoring Enabled by Virtual Well Metering - Chapter 1
    Media Type: Video

Credits

Earn credits by completing this course0.1 CEU credit1 PDH credit

Speakers

Dale EricksonDr. Dale Erickson serves as the Technical Authority and Technology Development Lead for Wood Group’s Digital Consulting Division. At Wood, he has pioneered the development of real-time, transient, multiphase flow simulators, leak detection systems, and control/optimization software for platforms/pipelines and wrote most of the core code for the multiphase pipeline simulator. In addition, he has been involved in numerous technical studies involving transient multiphase flow and dynamic process modelling. Since 1996, has had a significant role in over 100 projects, by providing functional design, detailed design approval, trouble shooting, tuning, quality review and testing and technical supervision. He first worked in the area of flow assurance by writing the first version of the Colorado School of Mines Hydrate program in 1983; then developed high accuracy Equations of State (EOS) in conjunction with NIST in Boulder, Colorado, for things like CO2 in the Critical Region, while getting his PhD from Rice University. He co-developed a thermal soil model enhancement and a bundle model enhancement for OLGA and developed the first commercial model for paraffin formation. He has recently developed a model of Oil Shale Well Operation, including a simplified Reservoir Model. His recent project deployments included a real-time on-line model for the largest CO2 Storage Network currently in operations.