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• Heat rates shown are from manufacturers’ specifications and are net of losses due to inlet and outlet pressure drop and parasitic power. • Available thermal energy (steam output) was calculated from information provided by the vendors or published turbine data on turbine exhaust temperatures and flows. • CHP steam estimates are based on an unfired HRSG producing dry, saturated steam at 150 psig. • Total efficiency is defined as the sum of the net electricity generated plus steam produced for plant thermal needs divided by total fuel input to the system. Higher steam pressures can be obtained but at slightly lower total efficiencies. Additional steam can be generated and total efficiency further increased with duct firing in the HRSG (see heat recovery section). • To estimate fuel savings effective electrical efficiency is a more useful value than overall efficiency. Effective electric efficiency is calculated assuming the useful thermal output from the CHP system would otherwise be generated by an 80 percent efficient boiler. The theoretical boiler fuel is subtracted from the total fuel input and the remaining fuel input used to calculate the effective electric efficiency which can then be compared to traditional electric generation. • The ratings in the table are all for systems operating in baseload (continuous) duty. Peaking and emergency power units generally have lower efficiency, lower capital cost, higher emissions, and are limited in their run hours. The data in the table show that electrical efficiency generally increases as combustion turbines become larger. As electrical efficiency increases, the absolute quantity of thermal energy available to produce steam decreases per unit of power output, and the ratio of power to heat for the CHP system increases. A changing ratio of power to heat impacts project economics and may affect the decisions that customers make in terms of CHP acceptance, sizing, and the desirability of selling power. It is generally recommended to size a CHP system based on a site’s thermal load demand; therefore, such power to heat ratios are important characteristics to consider. Table 3-2. Typical Performance for Gas Turbines in CHP Operation Cost & Performance Characteristics41 System 1 2 3 4 5 Net Electricity Capacity (kW) Installed Cost (2013 $/kW)42 Electric Heat Rate (Btu/kWh), HHV43 Electrical Efficiency (%), HHV Fuel Input (MMBtu/hr), HHV Required Fuel Gas Pressure (psig) 3,304 $3,281 14,247 23.95% 47.1 166.8 7,038 $2,080 11,807 28.90% 83.1 299.4 9,950 $1,976 12,482 27.34% 124.2 362.3 20,336 $1,518 10,265 33.24% 208.7 405.2 44,488 $1,248 9,488 35.96% 422.1 538 41 Data based on: 3 MW – Solar Turbines Centaur 40, 7 MW – Solar Taurus 70, 10 MW – Solar Mars 100, 20 MW – Solar Titan 250, 45 MW – GE LM6000. 42 Installed costs based on CHP system producing 150 psig saturated steam with an unfired heat recovery steam generator, gas compression, building, with SCR/CO/CEMS exhaust gas treatment in an uncomplicated installation at a customer site. 43 All turbine and engine manufacturers quote heat rates in terms of the lower heating value (LHV) of the fuel. Electric utilities measure power plant heat rates in terms of HHV and fuel prices are given in terms of the HHV. The ratio of LHV to HHV is approximately 0.9 for natural gas. Catalog of CHP Technologies 3–6 Combustion TubinesPDF Image | EPA CHP Technologies Combustion Turbines
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