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EPA Combined Heat and Power Partnership Biomass CHP Catalog O&M Issues As discussed under capital costs, additional O&M to the boiler section attributable to the addition of biomass for cofiring is minimal. Maintenance requirements for boilers cofiring biomass and coal are similar to those for coal-only boilers. However, slight changes to previous operational procedures, such as increasing overfire air and fuel feeder speeds, might be needed. Increases in O&M costs for biomass cofiring with coal are almost entirely for the biomass receiving and feed preparation. For a blended system, the adjustments to feed preparation O&M are also on the order of 15 to 30 percent of the cost of a dedicated biomass plant. Commercialization Status Organizations such as electric utilities, DOE, and the Electric Power Research Institute (EPRI), have conducted research and field tests on biomass cofiring in small- and large-scale utility boilers for a number of years. These tests have shown that cofiring with biomass has been successfully accomplished in a wide range of boiler types, including cyclone, stoker, pulverized coal, and bubbling and circulating fluidized bed boilers. According to the Federal Energy Management Program, at least 182 separate boilers and organizations in the United States have cofired biomass with fossil fuels although this number is not comprehensive. Of the 182 cofiring operations, 114 (or 63 percent) have been at industrial facilities, 32 at utility-owned power plants, 18 at municipal boilers, 10 at educational institutions, and eight at federal facilities61. 5.2 Gasification Technologies Biomass gasification for power production involves heating solid biomass in an oxygen-starved environment to produce a low or medium calorific gas. Depending on the carbon and hydrogen content of the biomass and the gasifier’s properties, the heating value of the syngas, can range anywhere from 100 to 500 Btu/cubic foot (10 to 50 percent that of natural gas). The heating value of syngas generally comes from CO and hydrogen produced by the gasification process. The remaining constituents are primarily CO2 and other incombustible gases. Biomass gasification offers certain advantages over directly burning the biomass because the gas can be cleaned and filtered to remove problem chemical compounds before it is burned. Gasification can also be accomplished using chemicals or biologic action (e.g., anaerobic digestion); however, thermal gasification is currently the only commercial or near commercial option. The fuel output from the gasification process is generally called syngas, though in common usage it might be called wood gas, producer gas, or biogas. Syngas can be produced through direct heating in an oxygen-starved environment, partial oxidation, or indirect heating in the absence of oxygen. Most gasification processes include several steps. The primary conversion process, called pyrolysis, is the thermal decomposition of solid biomass (in an oxygen-starved environment) to produce gases, liquids (tar), and char. Pyrolysis releases the volatile components of the biomass feed at around 1,100° F through a series of complex reactions. Biomass fuels are an ideal choice for pyrolysis because they have so many volatile components (70 to 85 percent on dry basis, compared to 30 percent for coal). The next step involves a further gasification process that converts the leftover tars and char into CO using steam and/or partial combustion. In coal gasification, pure oxygen or oxygen-enriched air is preferred as the oxidant because the resulting syngas produced has a higher heating value, and the process is more efficient. In biomass gasification, oxygen is generally not used because biomass ash has a lower melting point than coal ash, and because the scale of the plants is generally smaller. 61 DOE, 2004. 5. Biomass Conversion Technologies 45PDF Image | Biomass Combined Heat and Power Catalog of Technologies
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