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EPA Combined Heat and Power Partnership Biomass CHP Catalog inventory present in the unit makes it responsive to variable loads. Another advantage is that the fluidized bed can also maintain efficiency during system turn-down. Fluidized bed manufacturers have reported that the operating flexibility of their units has allowed their customers to take advantage of utility incentive programs for generation that follows electric demand.54 Table 5-3. Comparison of Stoker and Fluidized Bed Boilers Feature Boiler Type Stoker Fluidized Bed Combustion Mechanism Flow of solid fuel Combustion zone Mass transfer Combustion Control Responsiveness Excess air control Fuel Issues Applicability to various fuels Fuel pretreatment Environmental Factors Low sulfur oxide (SOx) combustion Low NOx combustion Appropriate facility size Equipment and Installed Costs Transported on stoker On the stoker Slow Slow response Difficult Fair Generally not necessary In-furnace desulfurization not possible Difficult Small Fluidized by combustion air and circulated through the combustion chamber and cyclone Entire area of the combustion furnace Active vertical movement-mass and heat transfer Quick response Possible High Lumps must be crushed High rate of in-furnace desulfurization Inherently low NOx Medium to large A biomass boiler system is a complex installation with many interrelated subsystems. An integrated steam system will include the fuel prep-yard and handling equipment, the boiler itself, induced and forced air fans, controls, and water treatment systems. Varying levels of emission control equipment will normally be needed as well. Most installations will include cyclone separators to capture large fly ash, a baghouse for fine particulate matter (PM), and a dry scrubber system. NOx emissions control in stoker boilers is provided by a selective non-catalytic reduction system using urea or ammonia that is installed in the top of the boiler. Other control equipment includes acid gas removal system, stack, ash handling, and continuous emissions monitoring equipment if required. Table 5-4 provides total capital cost estimates (equipment and installation) for both stoker and circulating fluidized bed steam systems for three biomass fuel feed rates: 100 tons/day, 600 tons/day and 900 tons/day. These feed rates are comparable to steam systems producing 20,000; 150,000 to 185,000; and 250,000 to 275,000 lb/hr of steam, respectively, depending on steam temperature and pressure. Installed costs can vary significantly depending on the scope of the equipment included, output steam conditions, geographical area, competitive market conditions, site requirements, emission control requirements, and prevailing labor rates. The estimates presented in the table are budgetary estimates based on published data and discussions with equipment suppliers and developers. The estimates are 54 Energy Product of Idaho, n.d. 5. Biomass Conversion Technologies 38PDF Image | Biomass Combined Heat and Power Catalog of Technologies
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