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Cost-Effectiveness of Distributed Generation Technologies A.5.2 Past SGIP Applications As of the end of 2009, over 140 microturbines had been installed under the SGIP. Table A-33 lists characteristics of microturbines deployed under the SGIP including number of installations, total rebated IC engine capacity (in MW), average installation capacity (kW) and average installed cost ($/kW) broken out by IOU territory as well as by natural gas or biogas fuel type. Nearly 90% of the installed microturbine systems were fueled by natural gas and accounted for close to 90% of the installed microturbine capacity. The remaining 10% of the microturbine systems were fueled by biogas. As expected, capital costs of biogas-fueled microturbines was nearly 40% higher than their natural gas-fueled counterparts. Table A-33: Summary of SGIP Microturbine Characteristics as of 12/31/2009 Natural Gas Biogas Number Capacity Avg Cost Number Capacity Avg Cost IOU (n) (MW) (kW) ($/Watt) (n) (MW) (kW) ($/Watt) PG&E 42 SCE 28 SDG&E 13 SCG 40 Subtotal: 123 8.2 196 5.3 190 1.1 87 7.0 175 21.7 176 4.19 14 3.07 - 3.06 4 2.75 - 3.35 18 2.0 146 5.09 0.0 - - 0.8 195 2.72 0.0 - - 2.8 157 4.56 A.5.3 Technology Operating Characteristics Performance of a microturbine can be evaluated based on the electrical conversion efficiency and heat rate. Electrical Efficiency Similar to gas turbines, microturbine electrical efficiency can be tied to heat rate through the following equation: Two common microturbine systems used in the U.S. marketplace are the Capstone C65 and the Ingersoll Rand MT 250. According to the manufacturer specification sheets, the heat rate for the Capstone C65 is 11,800 Btu/kWh (LHV), while the heat rate for the Ingersoll Rand MT 250 is Itron, Inc. Appendix A-56 DG TechnologiesPDF Image | Cost-Effectiveness of Distributed Generation Technologies
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