Comparison of Preanode and Postanode Carbon Dioxide Separation for IGFC Systems

2010 ◽  
Vol 132 (6) ◽  
Author(s):  
Eric Liese
Keyword(s):  
Fuel Cell ◽  
Power Density ◽  
Co2 Capture ◽  
Coal Gasification ◽  
Combined Cycle ◽  
Energy Technology ◽  
Integrated Gasification Combined Cycle ◽  
Lower Efficiency ◽  
Integrated Gasification ◽  
Cold Gas

This paper examines the arrangement of a solid oxide fuel cell (SOFC) within a coal gasification cycle, this combination generally being called an integrated gasification fuel cell cycle. This work relies on a previous study performed by the National Energy Technology Laboratory (NETL) that details thermodynamic simulations of integrated gasification combined cycle (IGCC) systems and considers various gasifier types and includes cases for 90% CO2 capture (2007, “Cost and Performance Baseline for Fossil Energy Plants, Vol. 1: Bituminous Coal and Natural Gas to Electricity,” National Energy Technology Laboratory Report No. DOE/NETL-2007/1281). All systems in this study assume a Conoco Philips gasifier and cold-gas clean up conditions for the coal gasification system (Cases 3 and 4 in the NETL IGCC report). Four system arrangements, cases, are examined. Cases 1 and 2 remove the CO2 after the SOFC anode. Case 3 assumes steam addition, a water-gas-shift (WGS) catalyst, and a Selexol process to remove the CO2 in the gas cleanup section, sending a hydrogen-rich gas to the fuel cell anode. Case 4 assumes Selexol in the cold-gas cleanup section as in Case 3; however, there is no steam addition, and the WGS takes places in the SOFC and after the anode. Results demonstrate significant efficiency advantages compared with IGCC with CO2 capture. The hydrogen-rich case (Case 3) has better net electric efficiency compared with typical postanode CO2 capture cases (Cases 1 and 2), with a simpler arrangement but at a lower SOFC power density, or a lower efficiency at the same power density. Case 4 gives an efficiency similar to Case 3 but also at a lower SOFC power density. Carbon deposition concerns are also discussed.

Comparison of Pre-Anode and Post-Anode Carbon Dioxide Separation for IGFC Systems

2009 ◽  
Author(s):  
Eric Liese
Keyword(s):  
Fuel Cell ◽  
Power Density ◽  
Co2 Capture ◽  
Coal Gasification ◽  
Lower Efficiency ◽  
Carbon Dioxide Separation ◽  
Thermodynamic Simulations ◽  
Integrated Gasification ◽  
Fuel Cell Anode ◽  
Cold Gas

This paper examines the arrangement of a solid oxide fuel cell (SOFC) within a coal gasification cycle, this combination generally being called an integrated gasification fuel cell cycle (IGFC). This work relies on a previous study performed by the National Energy Technology Laboratory (NETL) that details thermodynamic simulations of IGCC systems and considers various gasifier types and includes cases for 90% CO2 capture [1]. All systems in this study assume a Conoco Philips gasifier and cold gas clean up conditions for the coal gasification system (Cases 3 and 4 in the NETL IGCC report). Four system arrangements, cases, are examined. Cases 1 and 2 remove the CO2 after the SOFC anode. Case 3 assumes steam addition, a water-gas-shift (WGS) catalyst and a Selexol process to remove the CO2 in the gas cleanup section, sending a hydrogen-rich gas to the fuel cell anode. Case 4 assumes Selexol in the cold-gas cleanup section as in Case 3; however, there is no steam addition and the WGS takes places in the SOFC, and after the anode. Results demonstrate significant efficiency advantages compared to IGCC with CO2 capture. The hydrogen-rich case (Case 3) has better net electric efficiency compared to typical post-anode CO2 capture cases (Cases 1 and 2), with a simpler arrangement and similar SOFC area. Case 4 gives an efficiency similar to Case 3, but at a lower SOFC power density, or a lower efficiency at the same power density. Carbon deposition concerns are also discussed.

Comparative Analysis of Hydrogen Combustion Power Plants Integrated With Coal Gasification and CO2 Removal

2006 ◽  
Author(s):  
Michele Vascellari ◽  
Daniele Cocco ◽  
Giorgio Cau
Keyword(s):  
Comparative Analysis ◽  
Co2 Capture ◽  
Power Plants ◽  
Coal Gasification ◽  
H2 Production ◽  
Combined Cycle ◽  
Co2 Removal ◽  
Integrated Gasification Combined Cycle ◽  
Integrated Gasification ◽  
High Temperature Steam

Two power generation systems with pre-combustion CO2 capture fuelled with hydrogen from coal gasification are analyzed and compared from a thermodynamic and economic standpoint. The first solution, referred as Integrated Gasification Combined Cycle with CO2 Removal (IGCC-CR), is fuelled with hydrogen produced by the integrated gasification section. The second, referred as Integrated Gasification Hydrogen Cycle (IGHC), is based on the oxycombustion of hydrogen, producing steam that expands through an advanced high temperature steam turbine. The two H2 production sections are similar for both power plants, some minor modifications having been made to achieve better integration with the corresponding power sections. System performance is investigated using coherent assumptions to enable comparative analysis on the same basis. The plants have overall efficiencies of around 39.8% for IGCC-CR and 40.6% for IGHC, slightly lower than conventional IGCCs (without CO2 capture) with a CO2 removal efficiencies of 91% and 100% respectively. Lastly a preliminary economic analysis shows an increase in the cost of electricity compared to conventional IGCCs of about 44% for IGCC-CR and 50% IGHC.

scholarly journals Simulation and optimization integrated gasification combined cycle by used aspen hysys and aspen plus

2015 ◽  
Vol 3 (1) ◽  
pp. 178
Author(s):  
Mohsen Darabi ◽  
Mohammad Mohammadiun ◽  
Hamid Mohammadiun ◽  
Saeed Mortazavi ◽  
Mostafa Montazeri
Keyword(s):  
Gas Turbine ◽  
Coal Gasification ◽  
Aspen Plus ◽  
Combined Cycle ◽  
Parameters Estimation ◽  
Integrated Gasification Combined Cycle ◽  
Support Tool ◽  
Simulation And Optimization ◽  
Aspen Hysys ◽  
Integrated Gasification

<p>Electricity is an indispensable amenity in present society. Among all those energy resources, coal is readily available all over the world and has risen only moderately in price compared with other fuel sources. As a result, coal-fired power plant remains to be a fundamental element of the world's energy supply. IGCC, abbreviation of Integrated Gasification Combined Cycle, is one of the primary designs for the power-generation market from coal-gasification. This work presents a in the proposed process, diluted hydrogen is combusted in a gas turbine. Heat integration is central to the design. Thus far, the SGR process and the HGD unit are not commercially available. To establish a benchmark. Some thermodynamic inefficiencies were found to shift from the gas turbine to the steam cycle and redox system, while the net efficiency remained almost the same. A process simulation was undertaken, using Aspen Plus and the engineering equation solver (EES).The The model has been developed using Aspen Hysys® and Aspen Plus®. Parts of it have been developed in Matlab, which is mainly used for artificial neural network (ANN) training and parameters estimation. Predicted results of clean gas composition and generated power present a good agreement with industrial data. This study is aimed at obtaining a support tool for optimal solutions assessment of different gasification plant configurations, under different input data sets.</p>

Analysis of Integrated Coal Gasification System/Compressed-Air Energy Storage Power Plant Concepts

1991 ◽  
Author(s):  
M. Nakhamkin ◽  
M. Patel ◽  
L. Andersson ◽  
P. Abitante ◽  
A. Cohn
Keyword(s):  
Energy Storage ◽  
Power Plant ◽  
Coal Gasification ◽  
Cost Effective ◽  
Combined Cycle ◽  
Compressed Air ◽  
Cost Comparison ◽  
Compressed Air Energy Storage ◽  
Integrated Gasification Combined Cycle ◽  
Integrated Gasification

This paper presents the results of a project targeted at developing cost effective power plant concept with integrated Coal Gasification System (CGS) and with Compressed Air Energy Storage (CAES) plant. The developed concepts, denoted as CGS/CAES, provide for continuous operation of CGS and the reheat turboexpander train which are high temperature components, thus improving their operation and extending life resource. A parametric thermodynamic analysis is performed for several CGS/CAES concepts differentiated by their turbomachinery parameters, CGS arrangements, operating cycles, and hours of daily generation. A qualitative cost estimate is made using a variety of sources including published EPRI reports and extensive in-house cost data. A technical and cost comparison is made to the Integrated Gasification Combined Cycle (IGCC) plant.

Evaluation of Using Supercritical Rankine Cycles in Integrated Coal Gasification Combined Cycles (IGCC)

2017 ◽  
Author(s):  
Henry A. Long ◽  
Ting Wang ◽  
Arian Thomas
Keyword(s):  
Coal Gasification ◽  
Energy Resource ◽  
Rankine Cycle ◽  
Combined Cycle ◽  
Modern World ◽  
Integrated Gasification Combined Cycle ◽  
Combined Cycles ◽  
Reduce Emissions ◽  
Integrated Gasification ◽  
Cycle Efficiency

Coal is a prominent energy resource in the modern world, particularly in countries with emerging economies. In order to reduce emissions, it is necessary to find a way to utilize coal in a cleaner manner, such as through supercritical and ultra-supercritical Rankine cycles and the Integrated Gasification Combined Cycle (IGCC). Two approaches — raising the boiler pressure and using a reheat scheme — have been proven to notably increase the Rankine cycle efficiency. Thus, this study aims to investigate the effects of implementing reheat and supercritical or ultra-supercritical pressure in the bottom Rankine cycle on the IGCC cycle efficiency. First, reference cases of a standalone Rankine cycle were studied with single and double reheat, including boiler pressure levels from subcritical to ultra-supercritical conditions, followed by similar combined cycle cases, and finally IGCC systems. The results indicate that the notable efficiency enhancement in the standalone subcritical Rankine cycle do not prevail in the studied IGCC systems. Thus, it is not economically worthwhile to implement supercritical or ultra-supercritical bottom Rankine cycles in IGCC applications.

Modeling of Ultra Superheated Steam Gasification in Integrated Gasification Combined Cycle Power Plant With Carbon Dioxide Capture

2008 ◽  
Author(s):  
Peng Pei ◽  
Manohar Kulkarni
Keyword(s):  
Carbon Dioxide ◽  
Power Plant ◽  
Co2 Capture ◽  
Superheated Steam ◽  
Carbon Dioxide Capture ◽  
Combined Cycle ◽  
Steam Gasification ◽  
Integrated Gasification Combined Cycle ◽  
Integrated Gasification ◽  
Gasification Technology

Integrated Gasification Combined Cycle (IGCC) is believed to be one of the most promising technologies to offer electricity and other de-carbon fuels with carbon capture requirement as well as to meet other emission regulations at a relatively low cost. As one of the most important parts, different gasification technologies can greatly influence the performance of the system. This paper develops a model to examine the feasibilities and advantages of using Ultra Superheated Steam (USS) gasification technology in IGCC power plant with carbon dioxide capture and storage (CCS). USS gasification technology converts coal into syngas by the endothermic steam reforming reaction, and the heat required for this reaction is provided by the sensible heat in the ultra superheated steam. A burner utilizes synthetic air (21% O2 and 79% H2O) to burn fuel gas to produce the USS flame for the gasification process. The syngas generated from USS gasification has a higher hydrogen fraction (more than 50%) then other gasification processes. This high ratio of hydrogen is considered to be desired for a “capture-ready” IGCC plant. After gas cleanup and water gas shift reaction, the syngas goes to the Selexol process for carbon dioxide removal. Detailed calculations and analysis are performed to test the performance of USS gasification technology used in IGCC generation systems. Final results such as net output, efficiency penalty for CO2 capture part, and net thermal efficiency are calculated and compared when three different coal types are used. This paper uses published data of USS gasification from previous research at the University of North Dakota. The model also tries to treat the IGCC with carbon dioxide capture system as a whole thermal system, the superheated steam used in USS gasification can be provided by extracting steam from the lower pressure turbine in the Rankine Cycle. The model will make reasonable use of various waste energies and steams for both mechanical and chemical processes to improve the performance of the plant, and incorporate CO2 capture system into the design concept of the power plant.

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