Brandon Perkins is the product marketing manager for Industrial Data Intelligence at GE Intelligent Platforms. He believes that data is the fuel of the 21st century and that the Industrial Internet will transform industries and economies by improving productivity, environmental stewardship and worker safety around the globe. He may be reached at firstname.lastname@example.org.
Turbine failure can result in unwanted downtime and costly repairs. Early detection is key to keeping the plant running at optimum efficiency. Software monitoring solutions provide the opportunity to schedule repairs during planned plant outages. This type of technology allows end users to monitor turbine and overall plant performance and proactively handle required maintenance.
Combustion Problem Solved at a Combined Cycle Power Plant
On March 6, a software monitoring solution detected an issue with three combustion turbine exhaust thermocouples during a steady state run that was the turbine's first run after a hot gas path inspection. As this combustion turbine varied load between 100 and 155 megawatts, intermittent deviations appeared in thermocouples 3, 4 and 6. The exhaust thermocouples were expected to have values between 1,100 and 1,200 F. Actual temperature measurements varied as much as 100 degrees below expected values.
Since this hardware was recently replaced, the end user was interested in further evaluating this combustion issue with the original equipment manufacturer (OEM). The OEM investigated and eventually replaced combustion nozzles 12 and 13 during a subsequent planned maintenance outage.
Finding this issue early helped to ensure the end user did not take a forced outage during its summer run season. This end user is under a long-term service agreement so it was not liable for the replacement costs of the combustion nozzles. The end user estimated that, by detecting this issue early and preventing a problem in the summer peak season, it was able to avoid more than $350,000 in lost power production revenue.
Sediment Identified on a Steam Turbine Condenser
In the end of December, a software detected an increase in steam turbine condenser backpressure, from a normal operational pressure of approximately 3 inches of mercury (inHg) (or 10.1 kilopascals (kPa)) to values as high as 6 inHg (or 20.3 kPa). The software provider notified the end user and began tracking the issue on regularly scheduled calls.
The plant discovered that the cooling tower had a chemistry upset. The upset deposited a light film of sediment on the condenser tubes. After a cleaning solution was introduced into the cooling system in mid-January, the condenser back pressure returned to normal.
Increases in the condenser backpressure reduced efficiency in the condenser, leading to a loss in revenue. The notification of this issue from the provider allowed the site to take preventive action to clean the system before further increases in the backpressure of the condenser occurred. The backpressure returned to model predictions after maintenance was performed. If this preventive measure had not been taken, backpressure could have continued to increase, resulting in a need to shut down the unit. This could cause a loss of production and increased maintenance costs.