scholarly journals Alternative Fuels for Combined Cycle Power Plants: An Analysis of Options for a Location in India

2020 ◽  
Vol 12 (8) ◽  
pp. 3330
Author(s):  
Guido Marseglia ◽  
Blanca Fernandez Vasquez-Pena ◽  
Carlo Maria Medaglia ◽  
Ricardo Chacartegui
Keyword(s):  
Power Plant ◽  
Power Plants ◽  
Alternative Fuels ◽  
Combined Cycle ◽  
Operating Conditions ◽  
Pollutant Emissions ◽  
The Sustainable Development ◽  
Economic Analyses ◽  
Carbon Dioxide Co2 ◽  
The Impact

The Sustainable Development Goals 2030 Agenda of United Nations raises the need of clean and affordable energy. In the pathway for more efficient and environmentally friendly solutions, new alternative power technologies and energy sources are developed. Among these, the use of syngas fuels for electricity generation can be a viable alternative in areas with high biomass or coal availability. This paper presents the energy, environmental and economic analyses of a modern combined cycle plant with the aim to evaluate the potential for a combined power plant running with alternative fuels. The goal is to identify the optimal design in terms of operating conditions and its environmental impact. Two possible configurations are investigated in the power plant presented: with the possibility to export or not export steam. An economic analysis is proposed to assess the plant feasibility. The effect of the different components in its performance is assessed. The impact of using four different syngases as fuel is evaluated and compared with the natural gas fuelled power cycle. The results show that a better efficiency is obtained for the syngas 1 (up to 54%), in respect to the others. Concerning pollutant emissions, the syngas with a GHG impact and lower carbon dioxide (CO2) percentage is syngas 2.

CCPP Operational Flexibility Extension Below 30% Load Using Reheat Burner Switch-Off Concept

2015 ◽  
Author(s):  
Dirk Therkorn ◽  
Martin Gassner ◽  
Vincent Lonneux ◽  
Mengbin Zhang ◽  
Stefano Bernero
Keyword(s):  
Gas Turbine ◽  
Power Plants ◽  
Fast Response ◽  
Combined Cycle ◽  
Pollutant Emissions ◽  
Inlet Temperature ◽  
Operational Flexibility ◽  
Part Load ◽  
Combustion Technology ◽  
The Impact

Highly competitive and volatile energy markets are currently observed, as resulting from the increased use of intermittent renewable sources. Gas turbine combined cycle power plants (CCPP) owners therefore require reliable, flexible capacity with fast response time to the grid, while being compliant with environmental limitations. In response to these requirements, a new operation concept was developed to extend the operational flexibility by reducing the achievable Minimum Environmental Load (MEL), usually limited by increasing pollutant emissions. The developed concept exploits the unique feature of the GT24/26 sequential combustion architecture, where low part load operation is only limited by CO emissions produced by the reheat (SEV) burners. A significant reduction of CO below the legal limits in the Low Part Load (LPL) range is thereby achieved by individually switching the SEV burners with a new operation concept that allows to reduce load without needing to significantly reduce both local hot gas temperatures and CCPP efficiency. Comprehensive assessments of the impact on operation, emissions and lifetime were performed and accompanied by extensive testing with additional validation instrumentation. This has confirmed moderate temperature spreads in the downstream components, which is a benefit of sequential combustion technology due to the high inlet temperature into the SEV combustor. The following commercial implementation in the field has proven a reduction of MEL down to 26% plant load, corresponding to 18% gas turbine load. The extended operation range is emission compliant and provides frequency response capability at high plant efficiency. The experience accumulated over more than one year of successful commercial operation confirms the potential and reliability of the concept, which the customers are exploiting by regularly operating in the LPL range.

An Expanded Cost of Electricity Model for Highly Flexible Power Plants

2012 ◽  
Vol 135 (1) ◽  
Author(s):  
S. Can Gülen ◽  
Indrajit Mazumder
Keyword(s):  
Power Generation ◽  
Power Plant ◽  
Gas Turbine ◽  
Power Plants ◽  
Combined Cycle ◽  
Plant Performance ◽  
Cost Of Electricity ◽  
Renewable Power ◽  
Effective Performance ◽  
The Impact

Cost of electricity (COE) is the most widely used metric to quantify the cost-performance trade-off involved in comparative analysis of competing electric power generation technologies. Unfortunately, the currently accepted formulation of COE is only applicable to comparisons of power plant options with the same annual electric generation (kilowatt-hours) and the same technology as defined by reliability, availability, and operability. Such a formulation does not introduce a big error into the COE analysis when the objective is simply to compare two or more base-loaded power plants of the same technology (e.g., natural gas fired gas turbine simple or combined cycle, coal fired conventional boiler steam turbine, etc.) and the same (or nearly the same) capacity. However, comparing even the same technology class power plants, especially highly flexible advanced gas turbine combined cycle units with cyclic duties, comprising a high number of daily starts and stops in addition to emissions-compliant low-load operation to accommodate the intermittent and uncertain load regimes of renewable power generation (mainly wind and solar) requires a significant overhaul of the basic COE formula. This paper develops an expanded COE formulation by incorporating crucial power plant operability and maintainability characteristics such as reliability, unrecoverable degradation, and maintenance factors as well as emissions into the mix. The core impact of duty cycle on the plant performance is handled via effective output and efficiency utilizing basic performance correction curves. The impact of plant start and load ramps on the effective performance parameters is included. Differences in reliability and total annual energy generation are handled via energy and capacity replacement terms. The resulting expanded formula, while rigorous in development and content, is still simple enough for most feasibility study type of applications. Sample calculations clearly reveal that inclusion (or omission) of one or more of these factors in the COE evaluation, however, can dramatically swing the answer from one extreme to the other in some cases.

Ansaldo Energia Gas Turbine Technology Developments

2018 ◽  
Author(s):  
A. D. Ramaglia ◽  
U. Ruedel ◽  
V. Stefanis ◽  
S. Florjancic
Keyword(s):  
Gas Turbine ◽  
Power Plants ◽  
Axial Flow ◽  
Assessment Method ◽  
Combined Cycle ◽  
Optimization Techniques ◽  
Operating Conditions ◽  
Multidisciplinary Optimization ◽  
Successful Operation ◽  
The Impact

The operating conditions of the gas turbine combined cycle (GTCC) power plants have significantly changed over the last few years and are directed towards an improved operational and fuel flexibility, increased GT power output and efficiency and improved component lifetime. The purpose of this paper is to provide an overview of the development, analysis and validation of modern gas turbine features, parts and components for the AE64.3, AE94.2, AE94.3A, the GT26 and GT36. The development of compressor blades with a low uncertainty using multidisciplinary optimization techniques is outlined while the lifetime of a welded rotor is quantified using a damage-tolerant lifetime assessment method based on experimental creep data. For the lateral dynamics of the shaft train a modal-based approach supported by elastic structures will be described. For the axial flow turbine, the aerodynamic and heat transfer related design and validation of film cooled vanes and blades will be introduced with a particular focus on the tip area, the platforms and the application of under-platform dampers. Furthermore, the impact of the combustor-turbine interface on the turbine vane aerodynamics and film cooling characteristics is shown. For the continued very successful operation of the Constant Pressure Sequential Combustion System (CPSC), the thermos-acoustic activities of can combustors as well as the rig-to-engine transferability are presented. Recent approaches to the development of SLM parts for turbine hardware, specifically the approach used to select process parameters and creation of preliminary material models will also be briefly summarized.

Flue Gas Recirculation in a Gas Turbine: Impact on Performance and Operational Behavior

2011 ◽  
Author(s):  
Frank Sander ◽  
Richard Carroni ◽  
Stefan Rofka ◽  
Eribert Benz
Keyword(s):  
Power Plant ◽  
Co2 Capture ◽  
Flue Gas ◽  
Power Plants ◽  
Combustion Process ◽  
Combined Cycle ◽  
Flue Gas Recirculation ◽  
Overall Performance ◽  
Gas Recirculation ◽  
The Impact

The rigorous reduction of greenhouse gas emissions in the upcoming decades is only achievable with contribution from the following strategies: production efficiency, demand reduction of energy and carbon dioxide (CO2) capture from fossil fueled power plants. Since fossil fueled power plants contribute largely to the overall global greenhouse gas emissions (> 25% [1]), it is worthwhile to capture and store the produced CO2 from those power generation processes. For natural-gas-fired power plants, post-combustion CO2 capture is the most mature technology for low emissions power plants. The capture of CO2 is achieved by chemical absorption of CO2 from the exhaust gas of the power plant. Compared to coal fired power plants, an advantage of applying CO2 capture to a natural-gas-fired combined cycle power plant (CCPP) is that the reference cycle (without CO2 capture) achieves a high net efficiency. This far outweighs the drawback of the lower CO2 concentration in the exhaust. Flue Gas Recirculation (FGR) means that flue gas after the HRSG is partially cooled down and then fed back to the GT intake. In this context FGR is beneficial because the concentration of CO2 can be significantly increased, the volumetric flow to the CO2 capture unit will be reduced, and the overall performance of the CCPP with CO2 capture is increased. In this work the impact of FGR on both the Gas Turbine (GT) and the Combined Cycle Power Plant (CCPP) is investigated and analyzed. In addition, the impact of FGR for a CCPP with and without CO2 capture is investigated. The fraction of flue gas that is recirculated back to the GT, need further to be cooled, before it is mixed with ambient air. Sensitivity studies on flue gas recirculation ratio and temperature are conducted. Both parameters affect the GT with respect to change in composition of working fluid, the relative humidity at the compressor inlet, and the impact on overall performance on both GT and CCPP. The conditions at the inlet of the compressor also determine how the GT and water/steam cycle are impacted separately due to FGR. For the combustion system the air/fuel-ratio (AFR) is an important parameter to show the impact of FGR on the combustion process. The AFR indicates how close the combustion process operates to stoichiometric (or technical) limit for complete combustion. The lower the AFR, the closer operates the combustion process to the stoichiometric limit. Furthermore, the impact on existing operational limitations and the operational behavior in general are investigated and discussed in context of an operation concept for a GT with FGR.

scholarly journals Offshore Power Plants Integrating a Wind Farm: Design Optimisation and Techno-Economic Assessment Based on Surrogate Modelling

Processes ◽  
2018 ◽  
Vol 6 (12) ◽  
pp. 249 ◽  
Author(s):  
Luca Riboldi ◽  
Lars Nord
Keyword(s):  
Carbon Dioxide ◽  
Power Plant ◽  
Wind Farm ◽  
Combined Cycle ◽  
Operating Conditions ◽  
Oil Field ◽  
Total Carbon ◽  
Optimal Size ◽  
Surrogate Modelling ◽  
Carbon Dioxide Co2

The attempt to reduce the environmental impact of the petroleum sector has been the driver for researching energy efficient solutions to supply energy offshore. An attractive option is to develop innovative energy systems including renewable and conventional sources. The paper investigates the possibility to integrate a wind farm into an offshore combined cycle power plant. The design of such an energy system is a complex task as many, possibly conflicting, requirements have to be satisfied. The large variability of operating conditions due to the intermittent nature of wind and to the different stages of exploitation of an oil field makes it challenging to identify the optimal parameters of the combined cycle and the optimal size of the wind farm. To deal with the issue, an optimisation procedure was developed that was able to consider the performance of the system at a number of relevant off-design conditions in the definition of the optimal design. A surrogate modelling technique was applied in order to reduce the computational effort that would otherwise make the optimisation process unfeasible. The developed method was applied to a case study and the resulting optimal designs were assessed and compared to other concepts, with or without wind power integration. The proposed offshore power plant returned the best environmental performance, as it was able to significantly cut the total carbon dioxide (CO2) emissions in comparison to all the other concepts evaluated. The economic analysis showed the difficulty to repay the additional investment for a wind farm and the necessity of favourable conditions, in terms of gas and carbon dioxide (CO2) prices.

Thermo-Economic Evaluation of Solar Thermal and Photovoltaic Hybridization Options for Combined-Cycle Power Plants

2014 ◽  
Vol 137 (3) ◽  
Author(s):  
James Spelling ◽  
Björn Laumert
Keyword(s):  
Power Plant ◽  
Solar Energy ◽  
Power Plants ◽  
First Generation ◽  
Combined Cycle ◽  
Solar Thermal ◽  
Hybrid Power ◽  
Hybrid Power Plant ◽  
Carbon Dioxide Co2 ◽  
Solar Electricity

The hybridization of combined-cycle power plants with solar energy is an attractive means of reducing carbon dioxide (CO2) emissions from gas-based power generation. However, the construction of the first generation of commercial hybrid power plants will present the designer with a large number of choices. To assist decision making, a thermo-economic study has been performed for three different hybrid power plant configurations, including both solar thermal and photovoltaic hybridization options. Solar photovoltaic combined-cycle (SPVCC) power plants were shown to be able to integrate up to 63% solar energy on an annual basis, whereas hybrid gas turbine combined-cycle (HGTCC) systems provide the lowest cost of solar electricity, with costs only 2.1% higher than a reference, unmodified combined-cycle power plant. The integrated solar combined-cycle (ISCC) configuration has been shown to be economically unattractive.

Survey of Integrated Gasification Combined Cycle Power Plant Performance Estimates

1980 ◽  
Author(s):  
J. W. Larson
Keyword(s):  
Power Plant ◽  
Power Plants ◽  
Coal Gasification ◽  
Combined Cycle ◽  
Pollutant Emissions ◽  
Plant Performance ◽  
Integrated Gasification Combined Cycle ◽  
Technical Literature ◽  
Combined Cycle Power Plant ◽  
Integrated Gasification

The idea of a combined cycle power plant integrated with a coal gasification process has attracted broad interest in recent years. This interest is based on unique attributes of this concept which include potentially low pollutant emissions, low heat rate and competitive economics as compared to conventional steam plants with stack gas scrubbing. Results from a survey of technical literature containing performance and economic predictions have been compiled for comparison and evaluation of this new technique. These performance and economic results indicate good promise for near-term commercialization of an integrated gasification combined cycle power plant using current gas turbine firing temperatures. Also, these data show that advancements in turbine firing temperature are expected to provide sufficiently favorable economics for the concept to penetrate the market now held by conventional steam power plants.

Incremental Cost of CO2 Reduction in Power Plants

2002 ◽  
Author(s):  
Ram G. Narula ◽  
Harvey Wen ◽  
Kenneth Himes
Keyword(s):  
Incremental Cost ◽  
Co2 Emissions ◽  
Power Plants ◽  
Alternative Fuels ◽  
Co2 Reduction ◽  
Combined Cycle ◽  
Co2 Removal ◽  
Integrated Gasification Combined Cycle ◽  
The Cost ◽  
The Impact

Carbon dioxide (CO2) emissions from fossil-fueled power plants contribute to more than one-third of all CO2 emissions in the U.S. [1]. Any effort to curtail greenhouse gases should therefore include the reduction of this emission source. Methods of CO2 reduction include (1) use of alternative fuels with lower CO2 emissions and (2) CO2 scrubbing and sequestration to prevent its release to the atmosphere. The cost of CO2 reduction varies with the selected technology. This paper compares (1) the cost of electricity (COE) without and with CO2 removal/avoidance and (2) the impact of the incremental cost of CO2 reduction on COE for different technology options, including replacing existing coal plants with natural-gas-fired combined cycle (NGCC), integrated gasification combined cycle (IGCC) with and without CO2 removal, pulverized coal (PC) with CO2 scrubber, and nuclear plants. Full and partial compliance with the Kyoto Protocol are addressed.

Gas Turbine Combined Cycle Flexibility: A Dynamic Model for Compressor Intake Conditioning Through a Heat-Pump

2019 ◽  
Author(s):  
Iacopo Rossi ◽  
Luca Piantelli ◽  
Alberto Traverso
Keyword(s):  
Air Temperature ◽  
Power Plants ◽  
Combined Cycle ◽  
Operating Conditions ◽  
Plant Performance ◽  
Cycle Performance ◽  
Ambient Conditions ◽  
Modeling Framework ◽  
Critical Feature ◽  
The Impact

Abstract The flexibility of power plants is a critical feature in energy production environments nowadays, due to the high share of non-dispatchable renewables. This fact dramatically increases the number of daily startups and load variations of power plants, pushing the current technologies to operate out of their optimal range. Furthermore, ambient conditions significantly influence the actual plant performance, creating deviations against the energy sold during the day-ahead and reducing the profit margins for the operators. A solution to reduce the impact of unpredicted ambient conditions, and to increase the flexibility margins of existing combined cycles, is represented by the possibility of dynamically controlling the temperature at compressor intake. At present, cooling down the compressor intake is a common practice to govern combined cycle performance in hot regions such as the Middle East and Africa, while heating up the compressor intake is commonly adopted to reduce the Minimum Environmental Load (MEL). However, such applications involve relatively slow regulation of air intake, mainly coping with extreme operating conditions. The use of continuously varying, at a relatively quick pace, the air temperature at compressor intake, to mitigate ambient condition fluctuations and to cope with electrical market requirements, involves proper modeling of the combined cycle dynamic behavior, including the short-term and long-term impacts of intake air temperature variations. This work presents a dynamic modeling framework for the whole combined cycle applied to one of IREN Energia’s Combined Cycle Units. The paper encloses the model validation against field data of the target power plant. The validated model is then used to show the potential in flexibility augmentation of properly adjusting the compressor intake temperature during operation.

Consideration of the Environmental Impact of Wet vs Dry Cooling for Combined Cycle Power Plants

2014 ◽  
Author(s):  
A. G. Howell
Keyword(s):  
Environmental Impact ◽  
Power Plants ◽  
Combined Cycle ◽  
Regulatory Agencies ◽  
Cooling Systems ◽  
Increasing Trend ◽  
Carbon Dioxide Co2 ◽  
The Impact ◽  
Dry Cooling ◽  
Selection Of

Combined cycle power plants fueled with natural gas have been increasingly preferred by regulatory agencies for new power generation projects, compared with traditional coal-fired plants. With growing concerns about water resource availability and the environmental impact of wet cooling systems, there has been an increasing trend for new combined cycle projects to incorporate dry cooling, often as a mandate for regulatory approval of the project. There appears to be little consideration given to the impact of less efficient dry cooling systems on unit efficiency, and particularly on increased fuel requirements and therefore carbon dioxide (CO2) emissions for a given power generating output. The trade-off between reduction of water use and increased fuel requirements with dry cooling should be included as part of the decision on the selection of cooling systems for new fossil plant construction.

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