CCS and Power Systems
Carbon Capture - Post-Combustion Capture
Application of a Heat Integrated Post-Combustion Carbon Dioxide Capture System with Hitachi Advanced Solvent into Existing Coal-Fired Power Plant
Performer: University of Kentucky
Project No: FE0007395
The University of Kentucky Center for Applied Energy Research (UK CAER) Team will develop a two megawatt thermal (0.7 megawatt electrical [MWe] equivalent) slipstream post-combustion CO2 capture system for a coal-fired power plant using novel concepts coupled with Hitachi’s proprietary solvent (H3-1). An innovative heat integration method will utilize waste heat from the carbon capture system while improving steam turbine efficiency. A two-stage stripping concept will be combined with the heat integration method to increase solvent capacity and capture rate in the CO2 scrubber. The advanced solvent utilized by the process has several advantages over conventional amine solvents such as 30 weight percent (wt%) monoethanolamine (MEA), including exhibiting lower heat of regeneration, higher capacity, and less solvent degradation. Previous laboratory and pilot-scale tests of the H3-1 solvent, as well as results from an initial techno-economic analysis of the capture process, illustrate the potential of this CO2 capture system. Key features of the project are a two-stage stripping process for solvent regeneration and a heat-integrated cooling tower system that recovers waste energy from the carbon capture platform. The two-stage stripping process will increase solvent working capacity by providing a secondary air stripping column following the conventional steam stripping column. The air stripping stream will be sent to the boiler as combustion air to increase the CO2 content in the flue gas exiting the boiler. The integrated cooling tower system will use a liquid desiccant to dry the cooling tower air and waste heat to dry the liquid desiccant. The overall effect will be improved power plant cooling tower and steam turbine efficiency.
The project will be located at LG&E and KU Services Company’s E.W. Brown Generating Station, located near Harrodsburg, Kentucky. The design, start-up, and commissioning of the test facility will be performed with a generic 30 wt% MEA solvent to obtain baseline data for comparison with other proprietary solvents to be tested in the program. Testing will be conducted on two proprietary solvents: Hitachi’s advance amine solvent (H3-1), and a proprietary solvent developed by the CAER as an alternative solvent. Parametric testing and longterm verification campaigns will be conducted for each of the solvents. Corrosion evaluation and solvent degradation studies will be conducted concurrently with the verification runs. The potential heat integration, solvent and water management, and CO2 capture system stability and operability will be the main focal points. Process modeling will be performed to optimize the post-combustion CO2 capture system, determine power plant integration strategies, and conduct sensitivity analyses. The results of the modeling studies will be used to complete an economic analysis of the process to determine its capital and operating costs as well as to estimate the cost of electricity (COE) as compared to the reference MEA process.