Capital costs and energy considerations of different alternative stripper configurations for post combustion CO2 capture

2011 ◽  
Vol 89 (8) ◽  
pp. 1229-1236 ◽  
Author(s):  
Mehdi Karimi ◽  
Magne Hillestad ◽  
Hallvard F. Svendsen
Keyword(s):  
Co2 Capture ◽  
Capital Costs

System Integration and Techno-Economy Analysis of the IGCC Plant With CO2 Capture: Results of the EU H2-IGCC Project

2015 ◽  
Author(s):  
Mohammad Mansouri Majoumerd ◽  
Mohsen Assadi ◽  
Peter Breuhaus ◽  
Øystein Arild
Keyword(s):  
Co2 Capture ◽  
Capital Investment ◽  
Power Plants ◽  
System Analysis ◽  
Combined Cycle ◽  
Economic Evaluations ◽  
Extensive Literature ◽  
Capital Costs ◽  
Cost Of Electricity ◽  
Plant Components

The overall goal of the European co-financed H2-IGCC project was to provide and demonstrate technical solutions for highly efficient and reliable gas turbine technology in the next generation of integrated gasification combined cycle (IGCC) power plants with CO2 capture suitable for combusting undiluted H2-rich syngas. This paper aims at providing an overview of the main activities performed in the system analysis working group of the H2-IGCC project. These activities included the modeling and integration of different plant components to establish a baseline IGCC configuration, adjustments and modifications of the baseline configuration to reach the selected IGCC configuration, performance analysis of the selected plant, performing techno-economic assessments and finally benchmarking with competing fossil-based power technologies. In this regard, an extensive literature survey was performed, validated models (components and sub-systems) were used, and inputs from industrial partners were incorporated into the models. Accordingly, different plant components have been integrated considering the practical operation of the plant. Moreover, realistic assumptions have been made to reach realistic techno-economic evaluations. The presented results show that the efficiency of the IGCC plant with CO2 capture is 35.7% (lower heating value basis). The results also confirm that the efficiency is reduced by 11.3 percentage points due to the deployment of CO2 capture in the IGCC plant. The specific capital costs for the IGCC plant with capture are estimated to be 2,901 €/(kW net) and the cost of electricity for such a plant is 90 €/MWh. It is also shown that the natural gas combined cycle without CO2 capture requires the lowest capital investment, while the lowest cost of electricity is related to IGCC plant without CO2 capture.

CO2 Emissions Reduction From Coal-Fired Power Generation: A Techno-Economic Comparison

2016 ◽  
Vol 138 (6) ◽  
Author(s):  
Vittorio Tola ◽  
Giorgio Cau ◽  
Francesca Ferrara ◽  
Alberto Pettinau
Keyword(s):  
Power Generation ◽  
Co2 Capture ◽  
Coal Combustion ◽  
Carbon Dioxide Emissions ◽  
Power Plants ◽  
Co2 Storage ◽  
Carbon Capture And Storage ◽  
Combined Cycle ◽  
Comparative Performance ◽  
Capital Costs

Carbon capture and storage (CCS) represents a key solution to control the global warming reducing carbon dioxide emissions from coal-fired power plants. This study reports a comparative performance assessment of different power generation technologies, including ultrasupercritical (USC) pulverized coal combustion plant with postcombustion CO2 capture, integrated gasification combined cycle (IGCC) with precombustion CO2 capture, and oxy-coal combustion (OCC) unit. These three power plants have been studied considering traditional configuration, without CCS, and a more complex configuration with CO2 capture. These technologies (with and without CCS systems) have been compared from both the technical and economic points of view, considering a reference thermal input of 1000 MW. As for CO2 storage, the sequestration in saline aquifers has been considered. Whereas a conventional (without CCS) coal-fired USC power plant results to be more suitable than IGCC for power generation, IGCC becomes more competitive for CO2-free plants, being the precombustion CO2 capture system less expensive (from the energetic point of view) than the postcombustion one. In this scenario, oxy-coal combustion plant is currently not competitive with USC and IGCC, due to the low industrial experience, which means higher capital and operating costs and a lower plant operating reliability. But in a short-term future, a progressive diffusion of commercial-scale OCC plants will allow a reduction of capital costs and an improvement of the technology, with higher efficiency and reliability. This means that OCC promises to become competitive with USC and also with IGCC.

scholarly journals Turning CO2 Capture On and Off in Response to Electric Grid Demand: A Baseline Analysis of Emissions and Economics

2010 ◽  
Vol 132 (2) ◽  
Author(s):  
Stuart M. Cohen ◽  
Gary T. Rochelle ◽  
Michael E. Webber
Keyword(s):  
Co2 Emissions ◽  
Co2 Capture ◽  
Electricity Demand ◽  
System Level ◽  
Energy Requirements ◽  
Electric Grid ◽  
Peak Demand ◽  
Capital Costs ◽  
Generation Capacity ◽  
Co2 Capture Systems

Coal consumption accounted for 36% of America’s CO2 emissions in 2005, yet because coal is a relatively inexpensive, widely available, and politically secure fuel, its use is projected to grow in the coming decades (USEIA, 2007, “World Carbon Dioxide Emissions From the Use of Fossil Fuels,” International Energy Annual 2005, http://www.eia.doe.gov/emeu/iea/carbon.html). In order for coal to contribute to the U.S. energy mix without detriment to an environmentally acceptable future, implementation of carbon capture and sequestration (CCS) technology is critical. Techno-economic studies establish the large expense of CCS due to substantial energy requirements and capital costs. However, such analyses typically ignore operating dynamics in response to diurnal and seasonal variations in electricity demand and pricing, and they assume that CO2 capture systems operate continuously at high CO2 removal and permanently consume a large portion of gross plant generation capacity. In contrast, this study uses an electric grid-level dynamic framework to consider the possibility of turning CO2 capture systems off during peak electricity demands to regain generation capacity lost to CO2 capture energy requirements. This practice eliminates the need to build additional generation capacity to make up for CO2 capture energy requirements, and it might allow plant operators to benefit from selling more electricity during high price time periods. Post-combustion CO2 absorption and stripping is a leading capture technology that, unlike many other capture methods, is particularly suited for flexible or on/off operation. This study presents a case study on the Electric Reliability Council of Texas (ERCOT) electric grid that estimates CO2 capture utilization, system-level costs, and CO2 emissions associated with different strategies of using on/off CO2 capture on all coal-fired plants in the ERCOT grid in order to satisfy peak electricity demand. It compares base cases of no CO2 capture and “always on” capture with scenarios where capture is turned off during: (1) peak demand hours every day of the year, (2) the entire season of peak system demand, and (3) system peak demand hours only on seasonal peak demand days. By eliminating the need for new capacity to replace output lost to CO2 capture energy requirements, flexible CO2 capture could save billions of dollars in capital costs. Since capture systems remain on for most of the year, flexible capture still achieves substantial CO2 emissions reductions.

scholarly journals Post-combustion slipstream CO2-capture test facility at Jiangyou Power Plant, Sichuan, China: performance of a membrane separation module under dynamic power-plant operations

Clean Energy ◽  
2021 ◽  
Vol 5 (4) ◽  
pp. 742-755
Author(s):  
Qian Cui ◽  
Baodeng Wang ◽  
Xinglei Zhao ◽  
Guoping Zhang ◽  
Zhendong He ◽  
...  
Keyword(s):  
Power Plant ◽  
Host Plant ◽  
Co2 Capture ◽  
Power Plants ◽  
Membrane Separation ◽  
Operating Conditions ◽  
Test Facility ◽  
System Control ◽  
Capital Costs ◽  
Wide Range

Abstract Membrane-based separation technologies have the potential to lower the cost of post-combustion CO2 capture from power-plant flue gases through reduced energy and capital costs relative to conventional solvent approaches. Studies have shown promise under controlled conditions, but there is a need for data on performance and reliability under field conditions. Coal-fired power plants in China operate in a dynamic manner, with increases and decreases in output causing changes in flue-gas composition. In this paper, we describe the first field test of a membrane-based post-combustion CO2-capture system connected to a dynamically operating power plant in China. We report the performance of a Membrane Technology Research, Inc. (MTR) PolarisTM membrane-based capture system over a range of plant operating loads ranging from 54% to 84% and conducted an operational stability test over a 168-h period during which the power plant was operating at an average load of 55%, but ramped as high as 79% and as low as 55%. Our results confirm the ability of a membrane capture system to operate effectively over a wide range of host-plant operating conditions, but also identity several issues related to plant integration, system control and resilience in the face of host-plant upsets that require attention as membrane separation systems move towards commercial use.

Analysis of Flexible CO2 Capture Over an Investment Life Using a Dynamic Electric Grid Model

2010 ◽  
Author(s):  
John R. Fyffe ◽  
Stuart M. Cohen ◽  
Michael E. Webber ◽  
Gary T. Rochelle
Keyword(s):  
Carbon Dioxide ◽  
Co2 Emissions ◽  
Co2 Capture ◽  
Energy Requirement ◽  
System Level ◽  
Co2 Removal ◽  
Electric Grid ◽  
Modeling Framework ◽  
Capital Costs ◽  
Co2 Capture Systems

Global focus on greenhouse gas emissions has led the United State’s legislature to discuss various strategies to reduce carbon dioxide (CO2) emissions. With coal-fired plants responsible for roughly half of United States (U.S.) electricity generation and approximately 30% of the nation’s CO2 emissions, coal-fired plants will be largely affected by any future CO2 emission regulations. However, coal-based generation could continue to meet our electricity demands while complying with future CO2 emissions restrictions with the addition of carbon dioxide capture and sequestration (CCS) technology. Most studies of CCS systems have demonstrated a permanent energy requirement of 11–40% of a plant’s output when operating continuously at a 90% CO2 removal rate. This study, however, used a dynamic model of the Electric Reliability Council of Texas (ERCOT) electric grid to consider post-combustion CO2 capture systems that can operate flexibly. Post-combustion CO2 capture systems using chemical absorption and stripping are particularly suited for retrofitting existing plants and operating in a flexible manner. Flexible carbon capture allows plant operators to vary the energy used for CO2 capture and compression in order to regain this generation capacity when desirable. Thus, flexibility can be used to choose the CO2 capture rate that allows the most economical combination of operating costs, electricity price, and output levels. Furthermore, operating at lower CO2 capture energy requirement levels and increasing output capacity during peak demand periods could dramatically reduce the amount of replacement capacity needed to replace potential output lost when CO2 capture systems are in operation. This research uses an existing modeling framework of a dynamic hourly dispatch system to study the economic, environmental, and performance implications of flexible CO2 capture over an investment lifetime. The effects of CO2 prices, natural gas fuel prices, and replacement capacity costs were analyzed along with various operating strategies. The fuel mixture behavior and emissions effects are presented, showing that large emissions reductions can be achieved using the current ERCOT plant fleet with the addition of flexible CO2 capture. An annual system-level cash-flow analysis is used to determine a net present value (NPV) for a group of CO2 capture plants under a range of possible replacement capacity costs. If replacement capacity costs are accounted for, flexibility can improve the NPV of a CO2 capture investment by substantially lowering the associated capital costs to replace output lost to CO2 capture energy requirements.

scholarly journals A Process Intensification Approach for CO2 Absorption Using Amino Acid Solutions and a Guanidine Compound

Energies ◽  
2021 ◽  
Vol 14 (18) ◽  
pp. 5821
Author(s):  
Abishek Kasturi ◽  
Jorge F. Gabitto ◽  
Radu Custelcean ◽  
Costas Tsouris
Keyword(s):  
Amino Acid ◽  
Co2 Capture ◽  
Large Scale ◽  
Bubble Column ◽  
Process Intensification ◽  
Computer Code ◽  
Precipitation Reaction ◽  
Co2 Absorption ◽  
Capital Costs ◽  
Liquid Bubble

Environmentally friendly amino-acid salt solutions are used for the absorption of carbon dioxide from concentrated flue-gas streams via chemical absorption. Process intensification reduces operating and capital costs by combining chemical reactions and separation operations. Here, we present a new process-intensification approach that combines the CO2 capture and the amino-acid regeneration steps into a single process carried out in a slurry three-phase reactor. The absorbed CO2 precipitates as a solid carbonated guanidine compound. The cycle is completed by separation of the solid precipitate to strip the CO2 and regenerate the guanidine compound, while the liquid solution is recycled to the slurry reactor. The process was studied by modifying a model developed by the authors for a gas-liquid bubble column without the presence of the guanidine compound. The guanidine precipitation reaction was accounted for using kinetic parameters calculated by the authors in another study. The proposed model was implemented by modifying an existing computer code used for the simulation of gas-liquid bubble columns. The calculated results showed that the proposed cycle can significantly reduce energy, equipment, and operating costs and can make an important contribution to developing a competitive cost-effective large-scale process for CO2 capture.

A Fair Comparison Between Five Co2 Capture Technologies

2021 ◽  
Author(s):  
Amélie Cécile Martin ◽  
François Lacouture ◽  
Philip Llewellyn ◽  
Laurent Mariac
Keyword(s):  
Global Warming ◽  
Co2 Capture ◽  
Flue Gas ◽  
Carbon Capture ◽  
Waste Heat ◽  
Base Case ◽  
Case Scenario ◽  
Capital Costs ◽  
Wide Range ◽  
And Storage

Abstract To curtail the global warming increase to less than 2°C by 2050, the IPCC highlights Carbon Capture Utilization and Storage (CCUS) as a vital approach. TotalEnergies, following its ambition to become a responsible energy major, invests 10% of its R&D budget in CCUS to reduce the global process cost and help decarbonize our activities. TotalEnergies is both working to decarbonize its own assets and developing a transport and storage infrastructure in Europe, with notably Northern Lights an example of note. It is equally of interest how this transport/storage infrastructure can be of use for other sectors and as such how various full CCUS chains may emerge. This explains the interest to develop techno-economic tools to evaluate CO2 capture processes applied to a wide range of industries. CO2 that is an integral part of the manufacturing process, is particularly difficult to abate in any future scenario, and one particular industry, which is facing such a challenge is the cement sector. CCUS has been identified as a potential solution to help with this issue. The present paper outlines the outcomes of a techno-economic study evaluating CO2 capture technologies based on cement factory retrofitting. A literature review aimed at identifying the main characteristics of a typical European cement plant (capacity, process mode, pollutant composition in the flue gas…) was carried out. In this paper, a base case scenario of 90% absorption-based CO2 capture with monoethanolamine (MEA) is compared with four alternative CO2 capture approaches: –An absorption technology based on non-amine solvent.–An adsorption technology based on a Concentration Swing Adsorption process.–An oxyfuel technology derived from the R&D works performed during the CEMCAP project (European CO2 capture project).–A Calcium Looping technology with tail-end process configuration. For each of these approaches, the whole carbon capture chain has been considered: this includes flue gas pretreatment, CO2 conditioning (including compression), steam generation, and utilities. Using process simulations, engineering studies have been carried out and have provided Key Performance Indicators (KPIs) such as Capital Costs, Operation Costs and Global Warming Potential (primary energy consumption per ton of CO2 avoided). It enabled mapping the technologies with regards to the cost and volume of CO2 avoided, as well as providing for each of the technologies the break-even point for an eventual CO2 tax. Based on these KPIs, several facts have been highlighted: –The need to consider the whole process (including utilities, compression…) and not only the capture unit.–The development of new materials for adsorption and contactor design is already driving down costs.–The availability of waste heat can be a game-changer to implement a CO2 capture technology.–Technology comparisons are location and site-specific and cannot be taken as a basis for concept selection. TotalEnergies approach to CCUS is collaborative. With these full-scale techno-economical assessments, generated via quotations from industrial equipment providers and using Engineering, Procurement and Construction standards, this not only gives a basis for comparison, but also assists our discussions with partners to identify key technological development pathways.

Model of an Oxygen Transport Membrane for Coal Fired Power Cycles With CO2 Capture

2007 ◽  
Author(s):  
Frank Sander ◽  
Sebastian Foeste ◽  
Roland Span
Keyword(s):  
Co2 Capture ◽  
Oxygen Transport ◽  
Membrane Reactor ◽  
Operating Conditions ◽  
Separation Unit ◽  
Power Cycles ◽  
Capital Costs ◽  
Rate Of Increase ◽  
Oxygen Transport Membrane ◽  
The Impact

Greenhouse gas emissions from power generation will increase in future if the demand for electrical energy does not subside. Therefore capture and storage of carbon dioxide (CO2) will become important technologies for lowering the rate of increase of global CO2 emissions, or even reducing them. A promising technology for coal fired power cycles is the integrated gasification combined cycle (IGCC), where CO2 is separated from the syngas coming from the gasifier before the syngas is combusted in a more or less conventional gas turbine. But oxygen is required for the gasification process to achieve a high carbon conversion rate. The energy demand for the cryogenic air separation unit (ASU) lowers the net power output of the IGCC cycle. An alternative way of producing the oxygen could eliminate this disadvantage of the IGCC cycle. Oxygen transport membranes (also known as mixed conducting membranes – MCM) show a high potential for such applications in power cycles. In this paper results of an investigation on an IGCC cycle with CO2 capture and an integrated oxygen transport membrane (OTM) reactor are reported. The operating conditions of the membrane reactor have been analyzed; the feed inlet temperature and the pressure differences between permeate and retentate sides of the membrane reactor have been varied. The impact on the overall IGCC cycle has been discussed. The most optimistic assumptions give an overall net efficiency close to the case without CO2 capture. In this case the net efficiency is reduced by only 3 percentage points compared to an IGCC process without CO2 capture. But these assumptions lead to very challenging conditions for the membrane reactor. A pressure difference of 14.5 bar is assumed. Less severe operating conditions for the OTM reactor, which seem closer to realization, show less promising results. For sweep stream pressures of 10 and 15 bar the net efficiency ranges from 36% to 39%. This is in the range of an IGCC process with cryogenic ASU which achieves a net efficiency of 37% to 38%. It can be concluded that the integration of an OTM reactor into the IGCC cycle is an option with good prospects if the membrane is capable of bearing the challenging operating conditions. Calculations of investment costs have not been investigated in the frame of this work. Both the total capital costs and the durability are very important aspects for the membrane technology to be realized in power cycles such as IGCC.

scholarly journals Utilizing Solar Thermal Energy for Post-Combustion CO2 Capture

2010 ◽  
Author(s):  
Stuart M. Cohen ◽  
Michael E. Webber ◽  
Gary T. Rochelle
Keyword(s):  
Power Plant ◽  
Solar Energy ◽  
Co2 Capture ◽  
Electricity Generation ◽  
Energy System ◽  
Solar Thermal ◽  
Solar Thermal Energy ◽  
Parabolic Trough ◽  
Solar Systems ◽  
Capital Costs

There is broad scientific agreement that anthropogenic greenhouse gases are contributing to global climate change and that carbon dioxide (CO2) is the primary contributor. Coal-based electricity generation produces over 30% of U.S. CO2 emissions; however, coal is also an available, secure, and low cost fuel that currently provides roughly half of U.S. electricity. As the world transitions from the existing fossil fuel-based energy infrastructure to a sustainable energy system, carbon dioxide capture and sequestration (CCS) will be a critical technology to allow continued use of coal-based electricity in an environmentally acceptable manner. Post-combustion amine absorption and stripping is one leading CO2 capture technology that is relatively mature, available for retrofit, and amenable to flexible operation. However, standard system designs have high capital costs and can reduce plant output by approximately 30% due to energy requirements for solvent regeneration (stripping) and CO2 compression. A typical design extracts steam from the power cycle to provide CO2 capture energy, reducing net power output by 11–40%. One way to reduce the CO2 capture energy penalty while developing renewable energy technologies is to provide some or all CO2 capture energy with a solar thermal energy system. Doing so would allow greater power plant output when electricity demand and prices are the highest. This study presents an initial review of solar thermal technologies for supplying energy for CO2 capture with a focus on high temperature solar thermal systems. Parabolic trough and central receiver (power tower) technology appear technically able to supply superheated steam for CO2 compression or saturated steam for solvent stripping, but steam requirements depend strongly on power plant and CO2 capture system design. Evacuated tube and compound parabolic collectors could feasibly supply heat for solvent stripping. A parabolic trough system supplying the energy for CO2 compression and solvent stripping at a gross 500 megawatt-electrical coal-fired power plant using 7 molal MEA-based CO2 capture would require a total aperture area on the order of 2 km2 or more if sized for an average direct normal solar insolation of 561 W/m2. The solar system’s capital costs would be roughly half that of the base coal-fired plant with CO2 capture. This analysis finds that irrespective of capital costs, relatively high electricity prices are required for additional electricity sales to offset the operating and maintenance costs of the solar thermal system, and desirable operational periods will be further limited by the availability of sunlight and thermal storage. At CO2 prices near 50 dollars per metric ton of CO2, bypassing CO2 capture yields similar operating economics as using solar energy for CO2 capture with lower capital cost. Even at high CO2 prices, any operating profit improvement from using solar energy for CO2 capture is unlikely to offset system capital costs. For high temperature solar systems such as power towers and parabolic troughs, direct electricity generation is likely a more efficient way to use solar energy to replace output lost to CO2 capture energy. However, low temperature solar systems might integrate more seamlessly with solvent stripping equipment, and more rigorous plant design analysis is required to definitively assess the technical and economic feasibility of using solar energy for CO2 capture.

The Scottish Herring Trade, 1470–1600

2005 ◽  
Vol 84 (2) ◽  
pp. 149-165 ◽  
Author(s):  
Martin Rorke
Keyword(s):  
Sixteenth Century ◽  
West Coast ◽  
North West ◽  
Capital Costs ◽  
The North ◽  
East And West

This paper uses customs figures to show that herring exports from the east and west coast lowlands expanded significantly in the last six decades of the sixteenth century. The paper argues that the rise was primarily due to the north-west Highland fisheries being opened up and exploited by east and west coast burghs. These ventures required greater capital supplies and more complex organisation than their local inshore fisheries and they were often interrupted by political hostilities. However, the costs were a fraction of those required to establish a deepwater buss fleet, enabling Scotland to expand production and take advantage of European demand for fish while minimising additional capital costs.

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