Combined Cycle Gas Turbine Power Research Articles

ＬＮＧ火力発電所におけるＬＮＧ受入貯蔵・気化設備

Since 1969, many LNG receiving terminals have been constructed in Japan. This is in line with the Japanese policy of increasing the calorific value of city gas, and also changing the feedstock for thermal power plants to pollution-free LNG. In 1995, about 44 million tons of LNG were imported into Japan, and more than 70% of the LNG was used as fuel for power plants. Recently, advanced combined cycle gas-turbine power plants with higher thermal efficiency have been developed, and because LNG is more a suitable fuel for the plants than other fuels, the demand for LNG use in power plants is increasing. This paper presents a process outline of LNG receiving terminal for power plants and the main processing equipment, and mentions special consideration for the design of the LNG receiving terminal.

Combined Cycle Gas Turbine Power Plant With Coal Gasification and Solid Oxide Fuel Cell

The United States has extensive coal resources; thus, it is important to consider coal as a fuel for electric power production. This work presents a theoretical study of a novel high-efficiency coal-fired power plant. In the proposed combined cycle power plant, the Conoco coal gasification process is linked with solid oxide fuel cells (SOFC) and state-of-the-art gas turbines. The overall efficiency of such a plant can be around 60 percent, considering realistic heat, pressure, and other losses in the different components of the plant. If an additional steam turbine is incorporated, the overall efficiency can be increased to about 62 percent.

Power plant procurement in the 1990s

The major structural and policy changes implemented by National Power (UK) since privatisation in 1990 have impacted on major power plant project engineering, including procurement strategy for new major electrical/C&I installations. Two specific projects, Drax flue gas desulphurisation, authorised in 1989, and Didcot B combined-cycle gas turbine power station are compared in this paper.

An expert system for startup optimization of combined cycle power plants under NO/sub x/ emission regulation and machine life management

This paper proposes an expert system which optimizes the startup schedule for gas and steam turbine combined cycle power plants. The speed-up and load-up pattern of the plant is automatically optimized through an iterative process. Plant dynamics models representing quantitative knowledge and fuzzy rules representing qualitative knowledge are alternately used in the optimization process to modify the schedule parameters. The rules represent expertise on causal relations between modification rates of the schedule parameters and operational margins for constraints, i.e. NO/sub x/ emission and machine thermal stresses. Simulation analysis with a three pressure staged reheat type 235.7 MW rated capacity plant shows that the system provides quick and economical plant startup under NO/sub x/ emission regulation and reliable machine life management. Startup energy loss is reduced due to the reduction in startup time. Furthermore, optimum operating conditions are quickly reached with the expert system.

96/00663 CFB operates at 2400 psig, with reheat, firing waste coal

The use of natural gas for power generation is becoming increasingly important in many regions in the world. Given that the combined cycle gas turbine (CCGT) power stations are lower in capital cost and carbon intensity than their coal-fired counterparts, natural gas fired power stations are considered a vital part of the transition to a low carbon economy. However, CCGTs are not themselves “low carbon” and in order to reach a carbon intensity of less than 50 kgCO2/MWh, it will be necessary to decarbonise them via CCS, with post-combustion CCS currently regarded as being a promising technology for this application. In this study, we present a detailed model of a 420 MW triple-pressure reheat CCGT and evaluate its technical and economic performance under full and part load conditions. We evaluate the technical performance of our CCGT model by comparison to an equivalent model implemented in Thermoflow THERMOFLEX and observe agreement of power output and efficiency to within 4.1% and the temperature profile within the HRSG within 2.9%. We further integrate the CCGT with a dynamic model of an amine based CCS process, and observe a reduction in the base plant efficiency from 51.84% at full-load and 50.23% at 60% load by 8.64% points at full-load and 7.93% points at 60% load. A core conclusion of this paper is that CCGT power plants equipped with post-combustion CCS technologies are well suited to dynamic operation, as might be required in an energy system characterised by high penetrations of intermittent renewable power generation.

96/00668 Coal/water slurry: Path to economical use of coal fines?

The use of natural gas for power generation is becoming increasingly important in many regions in the world. Given that the combined cycle gas turbine (CCGT) power stations are lower in capital cost and carbon intensity than their coal-fired counterparts, natural gas fired power stations are considered a vital part of the transition to a low carbon economy. However, CCGTs are not themselves “low carbon” and in order to reach a carbon intensity of less than 50 kgCO2/MWh, it will be necessary to decarbonise them via CCS, with post-combustion CCS currently regarded as being a promising technology for this application. In this study, we present a detailed model of a 420 MW triple-pressure reheat CCGT and evaluate its technical and economic performance under full and part load conditions. We evaluate the technical performance of our CCGT model by comparison to an equivalent model implemented in Thermoflow THERMOFLEX and observe agreement of power output and efficiency to within 4.1% and the temperature profile within the HRSG within 2.9%. We further integrate the CCGT with a dynamic model of an amine based CCS process, and observe a reduction in the base plant efficiency from 51.84% at full-load and 50.23% at 60% load by 8.64% points at full-load and 7.93% points at 60% load. A core conclusion of this paper is that CCGT power plants equipped with post-combustion CCS technologies are well suited to dynamic operation, as might be required in an energy system characterised by high penetrations of intermittent renewable power generation.

96/00666 Coal gasifier with char recycle

The use of natural gas for power generation is becoming increasingly important in many regions in the world. Given that the combined cycle gas turbine (CCGT) power stations are lower in capital cost and carbon intensity than their coal-fired counterparts, natural gas fired power stations are considered a vital part of the transition to a low carbon economy. However, CCGTs are not themselves “low carbon” and in order to reach a carbon intensity of less than 50 kgCO2/MWh, it will be necessary to decarbonise them via CCS, with post-combustion CCS currently regarded as being a promising technology for this application. In this study, we present a detailed model of a 420 MW triple-pressure reheat CCGT and evaluate its technical and economic performance under full and part load conditions. We evaluate the technical performance of our CCGT model by comparison to an equivalent model implemented in Thermoflow THERMOFLEX and observe agreement of power output and efficiency to within 4.1% and the temperature profile within the HRSG within 2.9%. We further integrate the CCGT with a dynamic model of an amine based CCS process, and observe a reduction in the base plant efficiency from 51.84% at full-load and 50.23% at 60% load by 8.64% points at full-load and 7.93% points at 60% load. A core conclusion of this paper is that CCGT power plants equipped with post-combustion CCS technologies are well suited to dynamic operation, as might be required in an energy system characterised by high penetrations of intermittent renewable power generation.

Thermodynamic Heating With Various Types of Cogeneration Plants and Heat Pumps

The thermodynamic heating method combines cogeneration power plants and heat pumps in order to maximize the heating energy that can be derived from a given amount of fuel. In doing this, unnecessary waste of primary energy and environmental damage can be prevented. In this paper, four cogeneration systems—combined cycle plants, steam and gas turbine power plants, and gas engines—and heat pump systems are investigated and compared with respect to fuel utilization for realistic site conditions. It is shown that the combined cycle cogeneration power plant is superior to the other three types of power plant.

Gas Turbine Bottoming Cycles: Triple-Pressure Steam Versus Kalina

The performance of a triple-pressure steam cycle has been compared with a single-stage Kalina cycle and an optimized three-stage Kalina cycle as the bottoming sections of a gas turbine combined cycle power plant. A Monte Carlo direct search was used to find the optimum separator temperature and ammonia mass fraction for the three-stage Kalina cycle for a specific plant configuration. Both Kalina cycles were more efficient than the triple pressure steam cycle. Optimization of the three-stage Kalina cycle resulted in almost a two percentage point improvement.

The 900 MW Combined Cycle Gas Turbine Power Station Project at Killingholme

PowerGen's 900 MW combined cycle gas turbine (CCGT) power station at Killingholme achieved full load output over two months before the scheduled date for full commercial load and less than 34 months after the turnkey contract was placed. This paper reviews the development of PowerGen's first CCGT power station, discusses the reasons for the choice of this type of plant and examines early operating experience. The contract strategy, a technical description of the plant, the project programme and the environmental impact of the plant relative to a conventional coal-fired power station are also included.

Developments in air separation

Important developments over the past few years are reviewed. The products of air separation are key commodity chemicals in the USA. Production levels of nitrogen and argon have increased by 50 to 60% during the last decade. Significant improvements have been made to cryogenic processes to reduce the energy consumption of nitrogen and increase argon recovery. New oxygen technology has focused on integration with coal-gasification gas-turbine combined cycle power generation. Non-cryogenic separation technologies have become established for smaller scale nitrogen and oxygen production. Methods for computer modelling are aiding the development of efficient adsorption processes for oxygen and nitrogen production. New membrane materials and processes have been developed for nitrogen production.

Gas turbine combined cycle power generation system topped by closed cycle MHD.

A new triple combined cycle which is topped by closed cycle MHD and bottomed by gas and steam turbines is proposed for natural gas and gasified coal-fired plants. This triple combined cycle shows a potential for higher plant efficiency and lower NOx emission level than a conventional gas turbine combined cycle. The optimum weight ratios of air to coal and stem to coal supplied to a gasifier are investigated for maximizing the plant efficiency and minimizing NOx emission level in the gasified coal-fired triple combined cycle.

Advanced Energy Conversion

Advanced energy conversion techniques with potential for coal and nuclear fuel usage, for implementing high thermal efficiency, and for resource/environmental conformance are reviewed. These include open combined-cycle gas-turbine power plants, closed-cycle gas-turbine power plants, magnetohydrodynamic power plants, potassium-steam binary-cycle power plants, low-temperature closed-cycle power plants, and fuel cell power plants. 197 references. (WHK)