The Experts below are selected from a list of 360 Experts worldwide ranked by ideXlab platform
Jon Gibbins - One of the best experts on this subject based on the ideXlab platform.
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enhanced operating flexibility and optimised off design operation of coal plants with post combustion Capture
Energy Procedia, 2014Co-Authors: Mathieu Lucquiaud, Hannah Chalmers, Eva Sanchez Fernandez, Niall Mac Dowell, Jon GibbinsAbstract:Abstract The inherent nature of electricity necessitates a permanent balance between generation and demand in electricity systems. This has obvious implications for the operation of CCS power plants in decarbonised electricity systems with inflexible nuclear and variable renewable supply. The low variable costs of nuclear and some intermittent renewable technology allow them to run as base-load generators and shift fossil fuel plants from base-load to mid- merit plants. CCS power plants can be expected to increasingly operate in ways to balance variations, sometimes simultaneously, in the production of some intermittent renewable technologies and variations in electricity demand, resulting in more frequent ramping and start/stop cycles. As a result, they may also operate over a wide output range to maintain the quality and security of electricity supply by providing ancillary services, e.g. capacity and energy reserve, to the electricity network. This work characterises the operating envelope, the performance and the corresponding compressed CO 2 flow of coal power plants for a range of loads, with or without voluntary by-pass of the Capture unit. Optimised part-load operating strategies provide novel insights into the additional capabilities of CCS power plants specifically designed for enhanced operating flexibility.
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effective retrofitting of post combustion co2 Capture to coal fired power plants and insensitivity of co2 abatement costs to base plant efficiency
International Journal of Greenhouse Gas Control, 2011Co-Authors: Mathieu Lucquiaud, Jon GibbinsAbstract:Abstract Existing coal-fired power plants were not designed to be retrofitted with carbon dioxide Post-Combustion Capture (PCC) and have tended to be disregarded as suitable candidates for carbon Capture and storage on the grounds that such a retrofit would be uneconomical. Low plant efficiency and poor performance with Capture compared to new-build projects are often cited as critical barriers to Capture retrofit. Steam turbine retrofit solutions are presented that can achieve effective thermodynamic integration between a Post-Combustion CO 2 Capture plant and associated CO 2 compressors and the steam cycle of an existing retrofitted unit for a wide range of initial steam turbine designs. The relative merits of these Capture retrofit integration options with respect to flexibility of the Capture system and solvent upgradability will be discussed. Provided that effective Capture system integration can be achieved, it can be shown that the abatement costs (or cost per tonne of CO 2 to justify Capture) for retrofitting existing units is independent of the initial plant efficiency. This then means that a greater number of existing power plants are potentially suitable for successful retrofits of Post-Combustion Capture to reduce power sector emissions. Such a wider choice of retrofit sites would also give greater scope to exploit favourable site-specific conditions for CCS, such as ready access to geological storage.
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techno economic assessment of future proofing coal plants with postcombustion Capture against technology developments
Energy Procedia, 2011Co-Authors: Mathieu Lucquiaud, Jon Gibbins, Hannah Chalmers, Xi Liang, Olivia Errey, Mohammad Abu ZahraAbstract:Abstract While CCS is demonstrated globally utilities will face a period with fast learning curves for Capture technologies. Technology and cost uncertainty is a topic of particular concern for first-movers. For Post-Combustion Capture plants, costs are expected to decrease in the future and improved solvents are likely to become commercially available after the first CCS plants have started operating. Given that power generation assets are usually paid back over extensive periods of time it is important that, in this context, the first generation of plants and any Capture-ready plants can be future-proofed to incorporate future technological improvements. This paper presents selected results from a forthcoming report commissioned by the IEAGHG. A methodology based on a sensitivity analysis of solvent properties is used to identify pieces of equipment, which contribute to locking-in performance with Capture. Finally, some principles for analysing power plant economics with improved solvents and assessing the potential financial benefits in competitive electricity market of mitigating these technology risks are examined.
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retrofitting co2 Capture ready fossil plants with post combustion Capture part 2 requirements for natural gas combined cycle plants using solvent based flue gas scrubbing
Proceedings of the Institution of Mechanical Engineers Part A: Journal of Power and Energy, 2009Co-Authors: Mathieu Lucquiaud, Hannah Chalmers, Priyesh A Patel, Jon GibbinsAbstract:AbstractA number of natural gas combined cycle (NGCC) power stations recently permitted in the UK have been required to be CO2 Capture ready so that carbon Capture and storage can be retrofitted once it is commercially viable (or legally required). Several options for future CO2 Capture from NGCC units can be envisaged including Post-Combustion Capture technology using flue gas scrubbing with aqueous solvents. When an NGCC plant is designed to be ready for a retrofit with Post-Combustion Capture, one of the most important technical considerations is the steam extraction pressure and flow to provide the energy necessary for solvent regeneration. This is determined by the choice of solvent used, but new solvents are being developed and the exact future requirements, in perhaps 10–20 years time, cannot be predicted. Ways in which designs for the steam cycle of NGCC plants can cope with this challenge are presented. Several alternatives to mitigate the loss of power output of NGCC plants retrofitted with post...
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retrofitting co2 Capture ready fossil plants with post combustion Capture part 1 requirements for supercritical pulverized coal plants using solvent based flue gas scrubbing
Proceedings of the Institution of Mechanical Engineers Part A: Journal of Power and Energy, 2009Co-Authors: Mathieu Lucquiaud, Jon GibbinsAbstract:AbstractRapid global deployment of carbon Capture and storage (CCS) requires a two-track approach. CCS needs to be deployed at scale as quickly as possible and other plants, if built without CCS, need to be built CO2 Capture ready (CCR) before they are retrofitted. In particular, coal plants are likely to continue to be built in large numbers in developing countries. CCS is not an immediate option for all or most of these plants, but it would be feasible to make large numbers of them CCR for subsequent retrofit of flue gas scrubbing systems for Post-Combustion Capture. This article will examine options for CCR steam turbines for such plants, showing that effective thermodynamic integration with the Capture equipment can be achieved for minimal additional cost. The performance will be compared with the retrofit of non-CCR steam turbine configurations. Finally, the uncertainty of CCS development will be discussed and the performance of the CCR steam turbine options proposed will be assessed for a range of f...
Mathieu Lucquiaud - One of the best experts on this subject based on the ideXlab platform.
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reducing the water usage of post combustion Capture systems the role of water condensation evaporation in rotary regenerative gas gas heat exchangers
Applied Energy, 2019Co-Authors: Laura Herraiz, Dougal Hogg, Jim Cooper, Mathieu LucquiaudAbstract:Abstract Water usage is expected to greatly increase when CO2 Capture is added to thermal power plants. A major contribution is the reduction of flue gases temperatures from 100 to 150 °C to 30–50 °C. The majority of studies to date propose the use of direct contact cooling, combining a cold water loop with water cooling. This article expands on a previous study of the same authors (Herraiz et al., 2015) proposing dry air-cooled options with rotary regenerative gas/gas heat exchangers, relying on ambient air as the cooling fluid, to eliminate the use of process and cooling water prior to the carbon Capture system. It proposes, for the first time, a new stand-alone model of a bi-sector air/gas rotary heat exchanger, which includes the contribution to heat transfer of condensation/evaporation when flue gases are cooled below the dew point. It shows that water condensation from the flue gases in one sector of the heat exchanger, enhances the total heat transfer rate, due to the diffusion of water through the non-condensable gases boundary layer. In order to maintain the cooling capacity of these rotary regenerative heat exchangers, initially designed to operate without condensation, this article shows that they should be designed with surface properties, gas velocities and heat transfer channel geometries with the aim of allowing water condensate to remain on the metal elements surface, and then evaporate into the air stream when the metal elements have rotated to the air side. The model also predicts the location of water condensation, so that enamelled elements can be incorporated to the cold-end tiers of metal elements and mitigate any possible long-term corrosion problems.
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a pilot scale study of dynamic response scenarios for the flexible operation of post combustion co2 Capture
International Journal of Greenhouse Gas Control, 2016Co-Authors: Paul Tait, Bill Buschle, Ilja Ausner, Prashant Valluri, Marc Wehrli, Mathieu LucquiaudAbstract:Abstract The ability to operate flexibly is critical for the future implementation of carbon Capture and storage (CCS) in thermal power plants. A dynamic test campaign examines the response of a CO 2 absorption/desorption pilot-scale plant to realistic changes in flue gas flow rates and steam supply, representative of the operation of a Natural gas combined cycle (NGCC) plant fitted with Post-Combustion Capture. Five scenarios, demonstrating the operational flexibility that is likely to be encountered in an energy market with significant penetration from intermittent renewables, are presented, with 30% monoethanolamine (MEA) as the absorbing solvent. It complements a wider effort on dynamic modelling of these systems where a lack of dynamic plant data has been reported. The campaign focuses on analysing critical plant parameters of the response of the pilot plant to a gas turbine shutdown, a gas turbine startup and three enhanced operational flexibility scenarios, including two for power output maximisation and one for frequency response with a rapid increase of steam supply to the reboiler. The campaign also demonstrates the use of continuous in situ solvent lean loading measurement with the use of a novel online continuous liquid sensor. It confirms that no significant barriers to flexible operation of amine Post-Combustion Capture are found, although there remains scope for the improvement of plant response. Solvent inventory and circulation times are found to have a significant effect on Capture rate during certain dynamic operations. A large solvent inventory increases total circulation times, which can result in additional time being required for the plant to return to steady state following a perturbation. The plant is forced to operate with a non-optimal Capture rate while the solvent loading at the absorber inlet stabilises is identified as a potential impact. Use of interim solvent storage and continuous online measurement of solvent CO 2 loading, combined with comprehensive knowledge of liquid circulation times and potential mixing effects, are suggested as methods for improving plant response to dynamic operation, thereby increasing CCS plant flexibility.
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enhanced operating flexibility and optimised off design operation of coal plants with post combustion Capture
Energy Procedia, 2014Co-Authors: Mathieu Lucquiaud, Hannah Chalmers, Eva Sanchez Fernandez, Niall Mac Dowell, Jon GibbinsAbstract:Abstract The inherent nature of electricity necessitates a permanent balance between generation and demand in electricity systems. This has obvious implications for the operation of CCS power plants in decarbonised electricity systems with inflexible nuclear and variable renewable supply. The low variable costs of nuclear and some intermittent renewable technology allow them to run as base-load generators and shift fossil fuel plants from base-load to mid- merit plants. CCS power plants can be expected to increasingly operate in ways to balance variations, sometimes simultaneously, in the production of some intermittent renewable technologies and variations in electricity demand, resulting in more frequent ramping and start/stop cycles. As a result, they may also operate over a wide output range to maintain the quality and security of electricity supply by providing ancillary services, e.g. capacity and energy reserve, to the electricity network. This work characterises the operating envelope, the performance and the corresponding compressed CO 2 flow of coal power plants for a range of loads, with or without voluntary by-pass of the Capture unit. Optimised part-load operating strategies provide novel insights into the additional capabilities of CCS power plants specifically designed for enhanced operating flexibility.
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effective retrofitting of post combustion co2 Capture to coal fired power plants and insensitivity of co2 abatement costs to base plant efficiency
International Journal of Greenhouse Gas Control, 2011Co-Authors: Mathieu Lucquiaud, Jon GibbinsAbstract:Abstract Existing coal-fired power plants were not designed to be retrofitted with carbon dioxide Post-Combustion Capture (PCC) and have tended to be disregarded as suitable candidates for carbon Capture and storage on the grounds that such a retrofit would be uneconomical. Low plant efficiency and poor performance with Capture compared to new-build projects are often cited as critical barriers to Capture retrofit. Steam turbine retrofit solutions are presented that can achieve effective thermodynamic integration between a Post-Combustion CO 2 Capture plant and associated CO 2 compressors and the steam cycle of an existing retrofitted unit for a wide range of initial steam turbine designs. The relative merits of these Capture retrofit integration options with respect to flexibility of the Capture system and solvent upgradability will be discussed. Provided that effective Capture system integration can be achieved, it can be shown that the abatement costs (or cost per tonne of CO 2 to justify Capture) for retrofitting existing units is independent of the initial plant efficiency. This then means that a greater number of existing power plants are potentially suitable for successful retrofits of Post-Combustion Capture to reduce power sector emissions. Such a wider choice of retrofit sites would also give greater scope to exploit favourable site-specific conditions for CCS, such as ready access to geological storage.
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techno economic assessment of future proofing coal plants with postcombustion Capture against technology developments
Energy Procedia, 2011Co-Authors: Mathieu Lucquiaud, Jon Gibbins, Hannah Chalmers, Xi Liang, Olivia Errey, Mohammad Abu ZahraAbstract:Abstract While CCS is demonstrated globally utilities will face a period with fast learning curves for Capture technologies. Technology and cost uncertainty is a topic of particular concern for first-movers. For Post-Combustion Capture plants, costs are expected to decrease in the future and improved solvents are likely to become commercially available after the first CCS plants have started operating. Given that power generation assets are usually paid back over extensive periods of time it is important that, in this context, the first generation of plants and any Capture-ready plants can be future-proofed to incorporate future technological improvements. This paper presents selected results from a forthcoming report commissioned by the IEAGHG. A methodology based on a sensitivity analysis of solvent properties is used to identify pieces of equipment, which contribute to locking-in performance with Capture. Finally, some principles for analysing power plant economics with improved solvents and assessing the potential financial benefits in competitive electricity market of mitigating these technology risks are examined.
Paul Feron - One of the best experts on this subject based on the ideXlab platform.
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amine based post combustion Capture technology advancement for application in chinese coal fired power stations
Energy Procedia, 2014Co-Authors: Paul Feron, Debra Fernandes, Graeme Puxty, Leigh Wardhaugh, Will Conway, Phil Green, Dan Maher, Ashleigh Cousins, Gao Shiwang, Liu LianboAbstract:Abstract The energy penalty of Post-Combustion Capture of CO 2 (PCC) presents a major hurdle in the application of this technology for CO 2 -emission reduction and CO 2 utilisation in China. Huaneng CERI and CSIRO have been collaborating since 2008 with the aim of developing low-cost, energy-efficient and environmentally benign amine- based PCC processes. This paper provides an update on recent advancements in this area which has focused on: – Development of new liquid absorbent formulations – Assessment of PCC process modifications – Pilot plant evaluation in two facilities; one in Australia and one in China. The intermediate results indicate excellent progress towards a halving of the energy penalty of amine based PCC processes.
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results from trialling aqueous nh3 based post combustion Capture in a pilot plant at munmorah power station absorption
Chemical Engineering Research & Design, 2011Co-Authors: Scott Morgan, Andrew Allport, Aaron Cottrell, James Mcgregor, Leigh Wardhaugh, Paul FeronAbstract:Abstract Australia's Commonwealth Scientific and Industrial Research Organization (CSIRO) and Delta Electricity have developed, commissioned and operated an A$7 million aqueous NH 3 based Post-Combustion Capture (PCC) pilot plant at the Munmorah black coal fired power station in Australia. The results from the pilot plant trials will be used to address the gap in know-how on application of aqueous NH 3 for Post-Combustion Capture of CO 2 and other pollutants in the flue gas and explore the potential of the NH 3 process for application in the Australia power sector. This paper is one of a series of publications to report and discuss the experimental results obtained from the pilot plant trials and primarily focuses on the absorption section. The pilot plant trials have confirmed the technical feasibility of the NH 3 based Capture process. CO 2 removal efficiency of more than 85% can be achieved even with low NH 3 content of up to 6 wt%. The NH 3 process is effective for SO 2 but not for NO in the flue gas. More than 95% of SO 2 in the flue gas is removed in the pre-treatment column using NH 3 . The mass transfer coefficients for CO 2 in the absorber as functions of CO 2 loading and NH 3 concentration have been obtained based on pilot plant data.
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exploring the potential for improvement of the energy performance of coal fired power plants with post combustion Capture of carbon dioxide
International Journal of Greenhouse Gas Control, 2010Co-Authors: Paul FeronAbstract:Abstract The application of Post-Combustion Capture (PCC) processes in coal fired power stations can result in large reductions of the CO 2 -emissions, but the consequential decrease in generation efficiency is an important draw-back. The leading PCC technology is based on chemical absorption processes as this technology is the one whose scale-up status is closest to full-scale Capture in power plants. The energy performance of this process is analysed in this contribution. The analysis shows that the potential for improvement of the energy performance is quite large. It is demonstrated that further development of the Capture technology and the power plant technology can lead to generation efficiencies for power plants with 90% CO 2 Capture which are equivalent to the current generation efficiencies without CO 2 Capture, i.e. 0.4 (HHV), leading to an additional resource consumption of 16%. These improvements are possible throughout a combined improvement for the Capture process and power generation processes.
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the potential for improvement of the energy performance of pulverized coal fired power stations with post combustion Capture of carbon dioxide
Energy Procedia, 2009Co-Authors: Paul FeronAbstract:Abstract The application of Post-Combustion Capture processes in coal fired power stations can result in large reductions of the CO2 emissions, but the consequential decrease in generation efficiency is an important draw-back. The leading PCC technology is based on an absorption process and the energy performance of this process is analysed. The analysis shows that the potential for improvement of the energy performance is quite large. In conclusion it is demonstrated that further development of the Capture technology and the power plant technology can lead to generation efficiencies for power plants with 90% CO2 Capture which are equivalent to the current efficiencies without CO2 Capture, i.e. 0.4 (HHV).
Peter Moser - One of the best experts on this subject based on the ideXlab platform.
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the wet electrostatic precipitator as a cause of mist formation results from the amine based post combustion Capture pilot plant at niederaussem
International Journal of Greenhouse Gas Control, 2015Co-Authors: Peter Moser, Sandra Schmidt, Knut Stahl, Gerald Vorberg, Gustavo A. Lozano, Torsten Stoffregen, Torsten RichterAbstract:Abstract The investigation of emission formation mechanisms – in particular for aerosol driven mist formation – and also the development and testing of emission reduction measures for amine based Post-Combustion Capture are essential parts of the joint development programme of BASF, Linde and RWE Power at the Post-Combustion Capture pilot plant at Niederaussem. During more than 28,000 operating hours with BASF's innovative Capture technology OASE blue® several emission mitigation systems have been evaluated under real power plant conditions. A wet electrostatic precipitator (WESP) is often regarded as a suitable option to avoid mist formation. In contrast to this, our investigations have shown that the WESP can cause aerosol formation by increasing the number concentration of ultrafine particles/droplets in the flue gas. Our results also indicate that this highly negative, voltage-dependent effect cannot be explained by a measurable increase of the SO3 concentration downstream of the WESP at the entrance of the CO2 absorber. Varying concentrations of SO2 in the flue gas – which can react to SO3 by ozone that is generated in the high-voltage field of the WESP – does not verifiably influence the entrainment. Low emission levels can be achieved by a special pre-treatment of the flue gas and by the so-called Dry Bed configuration.
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performance of mea in a long term test at the post combustion Capture pilot plant in niederaussem
International Journal of Greenhouse Gas Control, 2011Co-Authors: Peter Moser, Sandra Schmidt, Georg Sieder, Hugo Garcia, Torsten StoffregenAbstract:Abstract RWE Power, BASF and Linde entered into a cooperation in 2007 to adapt the CO2-scrubbing technology for application in power plants and to optimize significantly the technical and economic performance of CO2 Post-Combustion Capture. All aspects of the Capture process on the basis of new energy-efficient solvents developed by BASF and the improved plant technology by Linde are investigated in a pilot plant at RWE Power's lignite-fired power station in Niederaussem, Germany. Some 250 measurements and an online-gas analysis system allow a detailed validation of the operational performance of the plant and a precise determination of the energy demand for the CO2 Capture process. In extensive accompanying analysis programs, solvent stability and the formation of degradation products and emissions are investigated. Including commissioning, start up and extensive parameter studies, the pilot plant was in operation for more than 5000 h with 30%-weight MEA as benchmark solvent from mid-2009 until January 2010. During this time, all aspects of the optimized process configuration were tested and compared with modeling results and literature data. This paper describes the performance validation approach on the basis of the results of the measurement program (specific energy demand: 3.5 GJ/tCO2) and the investigation of the time-dependence of MEA degradation and organic acid formation under real power plant operating conditions (MEA loss: 0.3 kg/tCO2; after 5000 h of operation weight-related content of acetate: 1.8%, formate: 0.2% and oxalate:
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investigation of trace elements in the inlet and outlet streams of a mea based post combustion Capture process results from the test programme at the niederaussem pilot plant
Energy Procedia, 2011Co-Authors: Peter Moser, Sandra Schmidt, Knut StahlAbstract:Abstract The first Post-Combustion Capture pilot plant in Germany was constructed and commissioned in July 2009 at BoA 1 in Niederaussem, the most advanced and efficient lignite-fired power plant unit in the world, as part of the joint development programme of RWE Power, BASF and Linde that is aiming at a highly efficient CO2-scrubbing technology for power plants. The test programme at the pilot plant focuses not only on the energy demand for CO2 Capture, solvent stability and corrosion resistance of innovative materials but also comprises an extensive analysis programme regarding emissions. Therefore, the pilot plant is in particular equipped with an online gas-analysis system to continuously measure the composition of the inlet and outlet gas streams. In addition, an extensive sampling and measurement programme is being carried out with the aim of making up the balance of trace elements in the gaseous flows including components that are normally not determined. For the liquid drain streams, a wide range of physical and chemical data is collected in parallel with the analysis of the gas streams. This paper summarises the results of the measurement programme and the operational experience regarding solvent losses for the benchmark solvent monoethanolamine (MEA). Some of the results are compared with the outcome of other test facilities by way of example.
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enabling post combustion Capture optimization the pilot plant project at niederaussem
Energy Procedia, 2009Co-Authors: Peter Moser, Sandra Schmidt, Georg Sieder, Hugo Garcia, Ilaria Ciattaglia, H KleinAbstract:Abstract In 2007 RWE Power, BASF and Linde entered into a cooperation to develop an optimized post combustion Capture technology for power plants. In mid-2009 a CO 2 Capture pilot plant will be commissioned at RWE Power’s lignite-fired power plant at Niederaussem, Germany. The pilot plant comprises all significant components of a large post combustion Capture plant but on a smaller scale. Some Capture process optimization measures are implemented that should increase the overall efficiency and reduce the costs of a commercial Capture plant. The design of the pilot plant - engineering, procurement and construction by Linde - allows testing the performance and stability of optimized CO 2 solvents, which BASF is currently developing. On the basis of an elaborated solvent selection methodology (pre-selection, screening, etc.) comprehensive experiments are carried out in order to examine solvent performance, and some measures for the optimization of the process configuration are developed. The 18-month pilot plant testing programme will allow the performance of the optimized solvent and the process to be evaluated.
Hannah Chalmers - One of the best experts on this subject based on the ideXlab platform.
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enhanced operating flexibility and optimised off design operation of coal plants with post combustion Capture
Energy Procedia, 2014Co-Authors: Mathieu Lucquiaud, Hannah Chalmers, Eva Sanchez Fernandez, Niall Mac Dowell, Jon GibbinsAbstract:Abstract The inherent nature of electricity necessitates a permanent balance between generation and demand in electricity systems. This has obvious implications for the operation of CCS power plants in decarbonised electricity systems with inflexible nuclear and variable renewable supply. The low variable costs of nuclear and some intermittent renewable technology allow them to run as base-load generators and shift fossil fuel plants from base-load to mid- merit plants. CCS power plants can be expected to increasingly operate in ways to balance variations, sometimes simultaneously, in the production of some intermittent renewable technologies and variations in electricity demand, resulting in more frequent ramping and start/stop cycles. As a result, they may also operate over a wide output range to maintain the quality and security of electricity supply by providing ancillary services, e.g. capacity and energy reserve, to the electricity network. This work characterises the operating envelope, the performance and the corresponding compressed CO 2 flow of coal power plants for a range of loads, with or without voluntary by-pass of the Capture unit. Optimised part-load operating strategies provide novel insights into the additional capabilities of CCS power plants specifically designed for enhanced operating flexibility.
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techno economic assessment of future proofing coal plants with postcombustion Capture against technology developments
Energy Procedia, 2011Co-Authors: Mathieu Lucquiaud, Jon Gibbins, Hannah Chalmers, Xi Liang, Olivia Errey, Mohammad Abu ZahraAbstract:Abstract While CCS is demonstrated globally utilities will face a period with fast learning curves for Capture technologies. Technology and cost uncertainty is a topic of particular concern for first-movers. For Post-Combustion Capture plants, costs are expected to decrease in the future and improved solvents are likely to become commercially available after the first CCS plants have started operating. Given that power generation assets are usually paid back over extensive periods of time it is important that, in this context, the first generation of plants and any Capture-ready plants can be future-proofed to incorporate future technological improvements. This paper presents selected results from a forthcoming report commissioned by the IEAGHG. A methodology based on a sensitivity analysis of solvent properties is used to identify pieces of equipment, which contribute to locking-in performance with Capture. Finally, some principles for analysing power plant economics with improved solvents and assessing the potential financial benefits in competitive electricity market of mitigating these technology risks are examined.
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retrofitting co2 Capture ready fossil plants with post combustion Capture part 2 requirements for natural gas combined cycle plants using solvent based flue gas scrubbing
Proceedings of the Institution of Mechanical Engineers Part A: Journal of Power and Energy, 2009Co-Authors: Mathieu Lucquiaud, Hannah Chalmers, Priyesh A Patel, Jon GibbinsAbstract:AbstractA number of natural gas combined cycle (NGCC) power stations recently permitted in the UK have been required to be CO2 Capture ready so that carbon Capture and storage can be retrofitted once it is commercially viable (or legally required). Several options for future CO2 Capture from NGCC units can be envisaged including Post-Combustion Capture technology using flue gas scrubbing with aqueous solvents. When an NGCC plant is designed to be ready for a retrofit with Post-Combustion Capture, one of the most important technical considerations is the steam extraction pressure and flow to provide the energy necessary for solvent regeneration. This is determined by the choice of solvent used, but new solvents are being developed and the exact future requirements, in perhaps 10–20 years time, cannot be predicted. Ways in which designs for the steam cycle of NGCC plants can cope with this challenge are presented. Several alternatives to mitigate the loss of power output of NGCC plants retrofitted with post...
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initial evaluation of the impact of post combustion Capture of carbon dioxide on supercritical pulverised coal power plant part load performance
Fuel, 2007Co-Authors: Hannah Chalmers, Jon GibbinsAbstract:Pulverised coal-fired plants often play an important role in electricity grids as mid-merit plants that can operate flexibly in response to changes in supply and demand. As a consequence, these plants are required to operate over a wide output range. This paper presents an initial evaluation of some potential impacts of adding Post-Combustion CO2 Capture on the part load performance of pulverised coal-fired plants. Preliminary results for ideal cases analysed using a simple high-level model indicate that Post-Combustion CO2 Capture could increase the options available to power plant operators. In particular, solvent storage could allow higher effective plant load factors to be achieved to assist with capital recovery while still permitting flexible operation for grid support. A number of areas for more detailed analysis are identified.