DOE is providing financial assistance under CCPI Round 3 to Hydrogen Energy California LLC (HECA), along with private capital cost sharing, to demonstrate an advanced coal-fired generating plant that co-produces electricity and fertilizer products. The project will employ integrated gasification combined cycle (IGCC) technology to nominally generate 400 megawatts (MWe) gross and up to 300 MWe (net) of electricity and produce approximately one million tons per year of fertilizer using a 75 percent sub-bituminous coal and 25 percent petroleum coke fuel blend. The fertilizer could be a combination of urea ammonium nitrate (UAN), urea, or other fertilizer equivalent, with the proportion dependent on market and commercial conditions. The CO2 off-take agreement contemplated by HECA will enable geologic storage of CO2 at a rate of approximately 2.6 million tonnes per year. The captured CO2 will be transported via pipeline to the Elk Hills oil field, approximately four miles from the power plant, for use in enhanced oil recovery (EOR). The design of these integrated facilities allows operating protocols that optimize: (1) the efficiencies of the physical plants while allowing steady state operation of the gasification unit; (2) the use of hydrogen to match product output volumes with demand under the terms of the urea/UAN and power off-take contracts; and (3) the use of the project’s capital investment. The project will utilize the Mitsubishi Heavy Industry (MHI) two-stage oxygen-blown gasification technology and combined cycle power block. A Rectisol® acid gas removal system will be employed to achieve the intended CO2 capture efficiency. Water quality and availability issues are addressed by utilizing local brackish groundwater treated on-site to meet all industrial process water requirements. The brackish groundwater will be supplied from the Buena Vista Water Storage District (BVWSD), which is a local water district with some groundwater sources not suitable for agricultural use. The project will also incorporate a Zero Liquid Discharge (ZLD) system. All project wastewater, including wastewater generated from the IGCC, raw water treatment, and cooling tower blowdown will be directed to ZLD system(s) with the recovered water recycled for reuse in the process. This further reduces the water demands of the project.
A need exists to further develop carbon management technologies that capture and store or beneficially reuse carbon dioxide (CO2) that would otherwise be emitted into the atmosphere from coal-based electric power generating facilities. Carbon capture and storage (CCS) technologies in enhanced oil recovery (EOR) or other economically practical applications offer great potential for reducing CO2 emissions and mitigating global climate change, while minimizing the economic impacts of the solution.
Under the Clean Coal Power Initiative (CCPI) Round 3 program, the U.S. Department of Energy (DOE) is providing financial assistance, including funding under the American Recovery and Reinvestment Act (ARRA) of 2009, to industry to demonstrate the commercial viability of technologies that will capture CO2 emissions and geologically store those emissions. Once demonstrated, the technologies can be readily considered in the commercial market-place by the electric power industry.
The project will be among the cleanest of any commercial solid fuel power plant built or under construction and will significantly exceed the emission reduction targets for 2020 established under the Energy Policy Act of 2005. In addition, emissions from the plant will be well below the California regulation requiring baseload plants to emit less greenhouse gases than comparably-sized natural gas combined cycle power plants.
Specific project benefits include:
The goal of the project is to design, build, and operate a greenfield, commercial scale, fully integrated, advanced IGCC power plant and fertilizer production facility with CCS in Kern County, California. The project is designed to achieve at least 90 percent CO2 capture efficiency while geologically storing approximately 2.6 million tonnes per year in an EOR application that will increase domestic oil production.
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