Monitoring Emissions

Testing and measurement solutions for gencos

Enhancing the operational efficiency of power plants as well as lowering their emission levels are the key driving forces to undertake testing and measurement (T&M) solutions at power plants. To this end, sensors and analysers are deployed to keep track of desired plant parameters. These solutions help in maintaining efficient combustion by regulating the air-fuel mix and boiler conditions. Meanwhile, T&M solutions such as continuous emission monitoring systems (CEMS) and predictive emission monitoring systems (PEMS) are gaining traction for their use in keeping track of emission levels and taking corrective measures.

Power Line takes a look at some such T&M solutions being adopted by gencos…

Emission monitoring

The Central Pollution Control Board (CPCB) has mandated the installation of CEMS for real-time pollution monitoring of stack emissions and continuous effluent quality monitoring system (CEQMS) for effluent quality monitoring in 17 categories of highly polluting industries, including power plants.

Gaseous emissions from the stack are one of the biggest sources of pollution from a typical power plant. The most concerning pollutants are NOx, SO2 and CO. With the tightening of emission norms post the MoEFCC’s notification in 2015, which specify norms for NOx, SOx and mercury, CEMS can now be used to measure emissions directly. CEMS are helpful in getting real-time data; providing remote accessibility to operators and regulators, greater transparency in monitoring performance, continuous performance check of air pollution control devices/treatment methods, time series analysis; and ensuring better compliance through self regulation and lower emissions.

CEMS usually employ complex extractive analysers, which remove flue gas sample from the duct and use a series of individual gas sensor modules or more advanced spectroscopic techniques to determine the composition. These sensitive analytical techniques require sample conditioning to avoid acidic condensation in the instrument, such as dilution with clean air, cooling to remove moisture, or heating the entire apparatus to above the dew point.

In the adoption of CEMS, utilities face challenges in terms of different monitoring systems and multiple instruments, different suppliers and multiple data formats, multiple platforms and multiple communication protocols, and data collection from heterogenous systems. Going forward, there is a need to have coherence between the central and state regulatory systems, clarity in CEMS audit protocol and a compliance mechanism. Further, there is a need for adopting best available technologies for CEMS and hand-holding instrument suppliers and service partners, besides having a uniform display system irrespective of vendor or supplier.

Although stack measurements can be used in combustion control, it is preferable to analyse flue gas as close to the combustion process as possible and at multiple locations in order to detect imbalances across the furnace. Such in-situ analysis can take the form of sensors placed directly in the flue gas, or line-of-sight optical absorption measurements in which a transmitter and a receiver are placed on either side of the duct or furnace. Various analytical methods are deployed for measuring and managing emissions from power plants. Paramagnetic analysers or electrochemical cells are useful in the measurement of various plant parameters.

Apart from this, measuring efficiency of various emission control devices used in a plant is essential. Analysers and probes are used to measure efficiency of the selective catalytic reduction (SCR) process. NOx and O2 are measured at the inlet and outlet to calculate the SCR removal efficiency. Besides this, often ammonia is monitored at the outlet to ensure that the ammonia slip is low so as to meet the emission limits and control contamination.

Another vital aspect of emission control in power plant operations is dust removal. Flue gases from coal-fired combustion are loaded with particulate matter, which must be cleaned before they are released into the atmosphere. This is done with an electrostatic precipitator or fabric filters. Correct operation of the filter is ensured by continuously monitoring dust concentration. Dust concentration or opacity is measured in stack emissions from a coal-fired power plant.

PEMS are software-based solutions that are able to provide reliable and accurate real-time emission estimations. PEMS exploit advanced mathematical models, which use process parameters (for example, pressure, temperatures, flow, etc.) as input variables. PEMS are suitable for all gas- and oil-fired emission sources, providing equal accuracy and data quality as traditional CEMS at much lower capex and opex costs. PEMS cannot measure emissions directly but use an empirical model to predict emissions based on historical and real-time process data. PEMS exist as stand-alone versions but are widely used as part of an integrated environmental monitoring approach capable of addressing multiple sources in one plant. When combined with data acquisition and handling systems, and integrated in plant-wide IT and communications networks, PEMS is a viable diagnostic tool to lower emissions and to improve combustion efficiency by surveillance of emission variations and associated changes in plant process conditions.

Monitoring combustion

Efficient fuel combustion is essential for cost-effective power generation and a reduction in emissions from a power plant. While sufficient air must be fed into the furnace to achieve complete coal combustion, too much air has the undesirable side effect of promoting NOx formation as more oxygen becomes available in the high temperature region of the flame. Raising the amount of air also lowers overall plant efficiency, as the increased volume of air flowing through the boiler leads to increased fan power consumption and greater heat losses.

Finding the right air-fuel mix in order to support efficient combustion has been a challenge. Controlling the air supplied to the combustion process is a fine balancing act. The ideal situation is to achieve a fuel-to-air ratio that minimises air as far as possible. However, operating at this point can present the risk of a plant running outside of its design parameters, wherein there may be too little air or excessive air.

One of the solutions for maintaining the right air-fuel mix is monitoring the flue gas oxygen. The level of oxygen present in the combustion waste gas is a key indicator of the amount of air supplied to the process. Oxygen measurement is therefore critical when optimising combustion for maximum efficiency. This can be done by using combustion gas oxygen analysers, which accurately measure the oxygen content in the combustion gas. Furthermore, these analysers can be used in conjunction with flow meters to regulate the amount of air supplied to the burner. Actuators can also be used to operate the plant at the optimum ratio of fuel, air and operating pressure. Improving the range and accuracy of the sensor information available from the boiler as well as using advanced control systems to maintain a balance between boiler variables and the optimum input settings for any given situation is also useful. In addition to this, sodium is a key parameter measured in the boiler. A highly sensitive online sodium monitor is needed to measure the sodium levels in critical dissolved compounds.

Monitoring feedwater

In order to achieve optimum performance of a coal-fired power plant, careful monitoring of quality of water and steam in the feedwater is essential. Multiple chemicals need to be monitored and controlled for optimum steam raising efficiency. Dissolved oxygen in the feedwater can cause pitting in the boiler, reducing its operating life. Dosing the feedwater with hydrazine reduces oxygen to form nitrogen and water. However, excess hydrazine is wasteful and costly, whereas too little is unable to adequately control the dissolved oxygen levels. Moreover, at high temperatures and pressures, ammonia is formed, which raises the feedwater pH level, increasing the risk of corrosion. Besides this, silica can hamper heat transfer efficiency and increase the risk of turbine malfunction by its precipitation on the blades. In order to tackle this, pH analysers for monitoring feedwater acidity or alkalinity and conductivity analysers to measure ionic content are used. By indicating the level of contamination, these can be used to decide the type and duration of treatment required. These are also useful in minimising boiler erosion.

Conclusion

T&M solutions are vital for maintaining operational efficiency of a power plant as well as lowering and maintaining emission levels. However, in order to obtain cost-effective outcomes from investment, it is essential to take into account various parameters such as the type of fuel used, the size of the plant, the age of the plant and the location of the plant.

 

 

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