Reference Info for J10
Text Reference:
B. J. Limb, E. J. Markey, R. Vercellino, S. D. Garland, M. D. Pisciotta, P. Psarras, D. R. Herber, T. M. Bandhauer, J. C. Quinn. 'Economic viability of using thermal energy storage for flexible carbon capture on natural gas power plants.' Journal of Energy Storage, 55(D), p. 105836, Nov 2022. doi: 10.1016/j.est.2022.105836
BibTeX Source:
@article{Limb2022c,
author = {Limb, Braden J and Markey, Ethan J and Vercellino, Roberto and Garland, Shane D and Pisciotta, Maxwell Douglas and Psarras, Peter and Herber, Daniel R and Bandhauer, Todd M and Quinn, Jason C},
title = {Economic viability of using thermal energy storage for flexible carbon capture on natural gas power plants},
journal = {Journal of Energy Storage},
volume = {55},
number = {D},
pages = {105836},
month = nov,
year = {2022},
doi = {10.1016/j.est.2022.105836},
pdf = {https://www.engr.colostate.edu/%7Edrherber/files/Limb2022c.pdf},
}Abstract:
Fossil fuel-based power plants generate 80% of the electricity in the United States and provide a reliable generation source for both base and peak power demands. These plants are expected to adapt to changes in environmental policies that will require carbon management with carbon capture and storage (CCS) representing a possible solution. Current solvent-based CCS has a detrimental impact on a power plant's performance due to large heat loads required for carbon capture solvent regeneration. This parasitic load restricts the power plant's output and operation flexibility. Therefore, this study evaluates the feasibility of using thermal storage technologies for natural gas combined cycle (NGCC) power plants coupled with CCS to minimize the impact of solvent regeneration and enable the plant to operate at peak power output. Thermal storage can minimize the impact of CCS on the power plant by providing the heat load required for solvent regeneration during times of peak demand which will allow the plant to operate unrestricted and at full power. In total, fifteen unique thermal storage configurations were evaluated from three thermal storage categories: Brayton cycle heat pump, vapor compression heat pump, and heat recovery steam generator steam extraction for storage. The viability of these systems was determined by evaluating each configuration on thousands of real-world Locational Marginal Pricing (LMP) profiles from the New York Independent System Operator and California Independent System Operator electricity markets using a techno-economic analysis. Results were compared to the performance of a base power plant (NGCC with CCS and no thermal storage) to determine the impact of thermal storage on power plant economics. Overall, six of the thermal storage configurations performed better than base CCS enabled power plant on between 11.5% - 38.7% of the LMP signals evaluated. The best performing configuration was a vapor compression heat pump that used flue gas as the working fluid and had both hot and cold thermal storage units. This configuration performed better than the base CCS power plant on 38.7% of the LMP profiles. The results of this study show thermal storage can mitigate the economic impact of carbon capture solvent regeneration on NGCC power plants. Discussion focuses on the impact of electricity pricing on the optimal thermal storage system, the advantages and disadvantages of the systems evaluated, and identifies limitations with the study.