Evaluation of options for CO{sub 2} capture/utilization/disposal

Abstract

The project objective is to develop engineering evaluations of technologies for the capture, use, and disposal of carbon dioxide (CO{sub 2}). This project emphasizes CO{sub 2}-capture technologies combined with integrated gasification combined-cycle (IGCC) power systems. Commercially available CO{sub 2}-capture technology is providing a performance and economic baseline against which to compare innovative technologies. The intent is to provide the CO{sub 2} budget, or an {open_quotes}equivalent CO{sub 2}{close_quotes} budget associated with each of the individual energy-cycle steps in addition to process design capital and operating costs. The value used for the {open_quotes}equivalent CO{sub 2}{close_quotes} budget is 1 kg CO{sub 2}/kWhe. The base case is a 458-MW (Gross) IGCC system using an O{sub 2}-blown Kellogg-Rust-Westinghouse (KRW) agglomerating fluidized bed gasifier, Illinois No. 6 bituminous coal feed and low-pressure glycol sulfur removal followed by a Claus/SCOT treatment to produce a salable product. Mining, feed preparation and conversion result in a net electric power production for the entire energy cycle of 411-MW with a 0.801 kg/kWhe CO{sub 2} release rate. For comparison, the gasifier output was taken through water-gas shift and then to either low-pressure glycol or chilled methanol for H{sub 2}S recovery; low-pressure glycol or membranes for CO{sub 2} recovery; and finally either a combustion turbine or fuel cell as the topping cycle. CO{sub 2} recovery was set at 80% for all cases so that the membrane system could be compared with the glycol on a consistent basis. The combustion turbine was then fed a high hydrogen content fuel. From the IGCC plant, a 500-km pipeline took the CO{sub 2} to geological sequestering. For the optimal case, the net electric power projection was reduced by 73-MW with a 0.277-kg/kWhe CO{sub 2}, release rate (when make-up power was considered).