Coal-fired power plants: operating conditions and costs of carbon capture and sequestration

2015 ◽  
pp. 275-282
Author(s):  
Frank P. Incropera
Keyword(s):  
Carbon Capture ◽  
Power Plants ◽  
Operating Conditions ◽  
Carbon Capture And Sequestration

Designing CO2 Transmission Pipelines Without Crack Arrestors

2010 ◽  
Author(s):  
Graeme G. King ◽  
Satish Kumar
Keyword(s):  
Wall Thickness ◽  
Carbon Capture ◽  
Power Plants ◽  
Oil And Gas ◽  
Cost Optimization ◽  
Operating Conditions ◽  
Operating Pressure ◽  
Design Work ◽  
Industrial Facilities ◽  
Pipeline Network

Masdar is developing several carbon capture projects from power plants, smelters, steel works, industrial facilities and oil and gas processing plants in Abu Dhabi in a phased series of projects. Captured CO2 will be transported in a new national CO2 pipeline network with a nominal capacity of 20×106 T/y to oil reservoirs where it will be injected for reservoir management and sequestration. Design of the pipeline network considered three primary factors in the selection of wall thickness and toughness, (a) steady and transient operating conditions, (b) prevention of longitudinal ductile fractures and (c) optimization of total project owning and operating costs. The paper explains how the three factors affect wall thickness and toughness. It sets out code requirements that must be satisfied when choosing wall thickness and gives details of how to calculate toughness to prevent propagation of long ductile fracture in CO2 pipelines. It then uses cost optimization to resolve contention between the different requirements and arrive at a safe and economical pipeline design. The design work selected a design pressure of 24.5 MPa, well above the critical point for CO2 and much higher than is normally seen in conventional oil and gas pipelines. Despite its high operating pressure, the proposed network will be one of the safest pipeline systems in the world today.

Cost Analysis of Carbon Capture and Sequestration from U.S. Natural Gas-Fired Power Plants

2020 ◽  
Vol 54 (10) ◽  
pp. 6272-6280 ◽  
Author(s):  
Peter Psarras ◽  
Jiajun He ◽  
Hélène Pilorgé ◽  
Noah McQueen ◽  
Alexander Jensen-Fellows ◽  
...  
Keyword(s):  
Natural Gas ◽  
Cost Analysis ◽  
Carbon Capture ◽  
Power Plants ◽  
Carbon Capture And Sequestration

scholarly journals Cost and U.S. public policy for new coal power plants with carbon capture and sequestration

2009 ◽  
Vol 1 (1) ◽  
pp. 4487-4494 ◽  
Author(s):  
Michael R. Hamilton ◽  
Howard J. Herzog ◽  
John E. Parsons
Keyword(s):  
Public Policy ◽  
Carbon Capture ◽  
Power Plants ◽  
Carbon Capture And Sequestration ◽  
Coal Power Plants ◽  
Coal Power

Qualification Testing of a Liquid CO2 Turbopump for Carbon Capture and Sequestration Applications

2011 ◽  
Author(s):  
J. Jeffrey Moore ◽  
Hector Delgado ◽  
Timothy Allison
Keyword(s):  
Carbon Dioxide ◽  
Power Plant ◽  
Carbon Capture ◽  
Power Plants ◽  
Pressure Rise ◽  
Department Of Energy ◽  
Minimal Amount ◽  
Carbon Capture And Sequestration ◽  
Liquid Co2 ◽  
Qualification Testing

In order to reduce the amount of carbon dioxide (CO2) greenhouse gases released into the atmosphere, significant progress has been made in developing technology to sequester CO2 from power plants and other major producers of greenhouse gas emissions. The compression of the captured carbon dioxide stream requires a sizeable amount of power, which impacts plant availability, capital expenditures and operational cost. Preliminary analysis has estimated that the CO2 compression process reduces the plant efficiency by 8% to 12% for a typical power plant. The goal of the present research is to reduce this penalty through development of novel compression and pumping processes. The research supports the U.S. Department of Energy (DOE) National Energy Technology Laboratory (NETL) objectives of reducing the energy requirements for carbon capture and sequestration in electrical power production. The primary objective of this study is to boost the pressure of CO2 to pipeline pressures with the minimal amount of energy required. Previous thermodynamic analysis identified optimum processes for pressure rise in both liquid and gaseous states. At elevated pressures, CO2 assumes a liquid state at moderate temperatures. This liquefaction can be achieved through commercially available refrigeration schemes. However, liquid CO2 turbopumps of the size and pressure needed for a typical power plant were not available. This paper describes the design, construction, and qualification testing of a 150 bar cryogenic turbopump. Unique characteristics of liquid CO2 will be discussed.

scholarly journals Improving the Carbon Capture Efficiency for Gas Power Plants through Amine-Based Absorbents

2020 ◽  
Vol 13 (1) ◽  
pp. 72
Author(s):  
Saman Hasan ◽  
Abubakar Jibrin Abbas ◽  
Ghasem Ghavami Nasr
Keyword(s):  
Climate Change ◽  
Flue Gas ◽  
Carbon Capture ◽  
Power Plants ◽  
Environmental Concern ◽  
Co2 Reduction ◽  
Operating Conditions ◽  
Circulation Rate ◽  
Co2 Removal ◽  
Reduction Of Co2

Environmental concern for our planet has changed significantly over time due to climate change, caused by an increasing population and the subsequent demand for electricity, and thus increased power generation. Considering that natural gas is regarded as a promising fuel for such a purpose, the need to integrate carbon capture technologies in such plants is becoming a necessity, if gas power plants are to be aligned with the reduction of CO2 in the atmosphere, through understanding the capturing efficacy of different absorbents under different operating conditions. Therefore, this study provided for the first time the comparison of available absorbents in relation to amine solvents (MEA, DEA, and DEA) CO2 removal efficiency, cost, and recirculation rate to achieve Climate change action through caron capture without causing absorbent disintegration. The study analyzed Flue under different amine-based solvent solutions (monoethanolamine (MEA), diethanolamine (DEA), and methyldiethanolamine (MDEA)), in order to compare their potential for CO2 reduction under different operating conditions and costs. This was simulated using ProMax 5.0 software modeled as a simple absorber tower to absorb CO2 from flue gas. Furthermore, MEA, DEA, and MDEA adsorbents were used with a temperature of 38 °C and their concentration varied from 10 to 15%. Circulation rates of 200–300 m3/h were used for each concentration and solvent. The findings deduced that MEA is a promising solvent compared to DEA and MDEA in terms of the highest CO2 captured; however, it is limited at the top outlet for clean flue gas, which contained 3.6295% of CO2 and less than half a percent of DEA and MDEA, but this can be addressed either by increasing the concentration to 15% or increasing the MEA circulation rate to 300 m3/h.

scholarly journals Air-Steam Gasification of Nigerian Lignite Coals for Hydrogen and Syngas Production

2020 ◽  
Author(s):  
Olagoke Oladokun ◽  
Bemgba B. Nyakuma
Keyword(s):  
Emerging Economies ◽  
Carbon Capture ◽  
Gas Production ◽  
Steam Gasification ◽  
Operating Conditions ◽  
Gas Composition ◽  
Carbon Capture And Sequestration ◽  
Syngas Production ◽  
Highly Sensitive ◽  
Harmful Effects

Abstract Coal is the fuel that drives most emerging economies. The gasification along with carbon capture and sequestration could ameliorate the harmful effects of coal utilisation. In this study, two recently discovered lignite coals; Obomkpa (BMK) and Ihioma (IHM) were examined for hydrogen and synthesis gas production through air-steam gasification using a non-stoichiometric model simulated in ASPEN Plus. The results showed that H2 production from BMK and IHM was highly sensitive to temperature and air but moderately sensitive to steam during gasification. The optimal operating conditions for BMK and IHM are; temperature 1125 °C and 1350 °C; equivalence ratio (ER) 0.26 and 0.26; steam/carbon ratio (S/C) 2.25 and 2.19, respectively. The optimal gas composition for BMK was; H2 (0.66), CO (0.18) and CO2 (0.18) mole-fraction, whereas for IHM was; H2 (0.65), CO (0.17) and CO2 (0.17). The findings indicate that both lignite coals are suitable feedstock for H2 and syngas production.

Effect of Impurities on Compressor and Cooler in Supercritical CO2 Cycles

2018 ◽  
Vol 141 (1) ◽  
Author(s):  
Ladislav Vesely ◽  
K. R. V. Manikantachari ◽  
Subith Vasu ◽  
Jayanta Kapat ◽  
Vaclav Dostal ◽  
...  
Keyword(s):  
Critical Point ◽  
Carbon Capture ◽  
Nuclear Power ◽  
Power Plants ◽  
High Efficiency ◽  
Waste Heat ◽  
Operating Conditions ◽  
Working Fluid ◽  
Compressor Inlet ◽  
Almost All

With the increasing demand for electric power, the development of new power generation technologies is gaining increased attention. The supercritical carbon dioxide (S-CO2) cycle is one such technology, which has relatively high efficiency, compactness, and potentially could provide complete carbon capture. The S-CO2 cycle technology is adaptable for almost all of the existing heat sources such as solar, geothermal, fossil, nuclear power plants, and waste heat recovery systems. However, it is known that optimal combinations of operating conditions, equipment, working fluid, and cycle layout determine the maximum achievable efficiency of a cycle. Within an S-CO2 cycle, the compression device is of critical importance as it is operating near the critical point of CO2. However, near the critical point, the thermo-physical properties of CO2 are highly sensitive to changes of pressure and temperature. Therefore, the conditions of CO2 at the compressor inlet are critical in the design of such cycles. Also, the impurity species diluted within the S-CO2 will cause deviation from an ideal S-CO2 cycle as these impurities will change the thermodynamic properties of the working fluid. Accordingly, the current work examines the effects of different impurity compositions, considering binary mixtures of CO2 and He, CO, O2, N2, H2, CH4, or H2S on various S-CO2 cycle components. The second part of the study focuses on the calculation of the basic cycles and component efficiencies. The results of this study will provide guidance and define the optimal composition of mixtures for compressors and coolers.

scholarly journals Membrane Processes for Direct Carbon Dioxide Capture From Air: Possibilities and Limitations

2021 ◽  
Vol 3 ◽  
Author(s):  
Christophe Castel ◽  
Roda Bounaceur ◽  
Eric Favre
Keyword(s):  
Carbon Capture ◽  
Power Plants ◽  
Large Scale ◽  
Energy Requirement ◽  
Production Capacity ◽  
Operating Conditions ◽  
Alkaline Solutions ◽  
Membrane Unit ◽  
Membrane Processes ◽  
The Impact

The direct capture of CO2 from air (DAC) has been shown a growing interest for the mitigation of greenhouse gases but remains controversial among the engineering community. The high dilution level of CO2 in air (0.04%) indeed increases the energy requirement and cost of the process compared to carbon capture from flue gases (with CO2 concentrations around 15% for coal power plants). Until now, solid sorbents (functionalized silica, ion exchange resins, metal–organic frameworks, etc.) have been proposed to achieve DAC, with a few large-scale demonstration units. Gas-liquid absorption in alkaline solutions is also explored. Besides adsorption and absorption, membrane processes are another key gas separation technology but have not been investigated for DAC yet. The objective of this study is to explore the separation performances of a membrane unit for CO2 capture from air through a generic engineering approach. The role of membrane material performances and the impact of the operating conditions of the process on energy requirement and module production capacity are investigated. Membranes are shown to require a high selectivity in order to achieve purity in no more than two stages. The specific energy requirement is globally higher than that of the adsorption and absorption processes, together with higher productivity levels. Guidelines on the possibilities and limitations of membranes for DAC are finally proposed.

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