The purpose of this paper is to aid systems analysts in the design, modeling, and assessment of advanced, gasification-based power generation systems featuring air separation units (ASUs) integrated with gas turbines adapted for syngas fuel. First, the fundamental issues associated with operating a gas turbine on syngas will be reviewed, along with the motivations for extracting air from the turbine-compressor and/or injecting nitrogen into the turbine expander. Configurations for nitrogen-only and air-nitrogen ASU integration will be described, including the benefits and drawbacks of each. Cryogenic ASU technology will be summarized for both low-pressure and elevated-pressure applications and key design and integration issues will be identified and discussed. Finally, membrane-based ASU technology will be described and contrasted with cryogenic technology in regard to system design and integration.
This paper discusses the performance benefits available from compressor discharge water injection in an indirect-fired gas turbine. The results of parametric performance studies are the main technical focus. The performance studies are part of the U.S. Department of Energy (DOE) Morgantown Energy Technology Center (METC) indirect-fired gas turbine program. The key technical approach is to develop a high-pressure, coal-fired ceramic heat exchanger to serve as the air heater. A high-pressure coal-fired ceramic air heater is now under development in a DOE-sponsored program at Hague International. The goal of this program is to develop a heat exchanger suitable for turbine inlet temperatures from 1,100 to 1,260 °C. With a turbine inlet temperature in this range, coal-fired indirect systems have performance superior to direct-fired gas-fueled simple cycle systems. Using conservative assumptions, the coal-fired indirect cycle has calculated net plant efficiencies in the 32 to 37 percent range, on a higher heating value (HHV) basis, at typical pressure ratios and 1,260 °C (2,300 °F) turbine inlet temperature. Adding a steam bottoming cycle raises the net plant efficiency (NPE) to 44–48 percent HHV. Adding water injection raises the simple cycle efficiency to 41–43 percent HHV and the combined cycle efficiency to 47–54 percent HHV. These NPE’s compare favorably to the most advanced industrial direct-fired systems. For example, a natural gas-fired GE MS7001-F has published HHV efficiencies of 31.1 percent simple cycle and 46.1 percent combined cycle (Gas Turbine World, 1990).
This paper examines two coal-based hybrid configurations that employ separated anode and cathode streams for the capture and compression of CO2. One system uses a single compressor to compress and partially preheat the cathode air flow. The second system replaces the single compressor with a two stage compression process with an intercooler to extract heat between the stages, and to reduce the work that is required to compress the air flow in the cathode stream. Calculations are presented for both systems with and without heat recuperation. For the single compressor system with heat recuperation the hybrid system assumes the form of a recuperated Brayton cycle; when the recuperator is not present the hybrid system assumes the form of a standard Brayton cycle. The calculation results show that an increase of 2.2% in system efficiency was obtained by staging the compression for these cycles.
This paper reviews the status of in situ gas stream cleanup technologies which are an integral part of the direct coal-fired gas turbine systems being developed through the U.S. Department of Energy (DOE), Morgantown Energy Technology Center (METC). The technical discussion focuses on the proof-of-concept systems under development in the DOE/METC Advanced Coal-Fueled Gas Turbine Systems (ACFGTS) program initiated in 1986. In this program, Solar Turbines Inc., the Allison Gas Turbine Division of General Motors Corporation, and Westinghouse Electric Corporation have completed bench-scale tests of integrated combustion and hot gas cleanup systems in preparation for full-size subsystem tests. All these projects include the development of cleanup systems for contaminants resulting from the combustion of coal. These systems will both control emissions of pollutants and protect the turbine gas path from fouling, erosion, and corrosion. The bench-scale tests have demonstrated efficient combustion of coal-water slurries (CWS) and dry coal in high-pressure, short residence-time combustors. The tests have also yielded promising results in the abatement of nitrogen oxides (NOx) and volatile alkali and in the removal of ash and sulfur species from the hot gas streams.
The U.S. Department of Energy (DOE) is conducting a program to develop ultra high-efficiency, cost-effective, environmentally benign gas turbine systems for industrial and utility applications. The Advanced Turbine Systems (ATS) Program, jointly managed by the DOE’s Office of Fossil Energy (DOE/FE) and Office of Conservation and Renewable Energy (DOE/CE), will lead to the commercial offering by industry of systems meeting full program goals by the years 2000–2002. It is expected that some advanced technology will already have been commercialized in intermediate systems before that time. Teams, led by U.S. turbine manufacturers, will conduct most of the development work in the ATS Program. However, a substantial technology base element of the program will see universities and others conduct significant research and development (R&D) on generic technology issues relevant to the program. The program is primarily aimed at developing natural gas-fired turbine systems. Although the conversion of ATS to firing with coal or biomass fuels will be addressed in the analysis of ATS, tests will not be conducted in the program to verify conversion to alternate fuel firing. The program will, however, include work to transfer advanced technology to the coal- and biomass-fueled systems being developed in other DOE programs.
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