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1
Langston, Lee S. "Cogeneration: Gas Turbine Multitasking." Mechanical Engineering 134, no. 08 (2012): 50. http://dx.doi.org/10.1115/1.2012-aug-4.
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This article describes the functioning of the gas turbine cogeneration power plant at the University of Connecticut (UConn) in Storrs. This 25-MW power plant serves the 18,000 students’ campus. It has been in operation since 2006 and is expected to save the University $180M in energy costs over its 40-year design life. The heart of the UConn cogeneration plant consists of three 7-MW Solar Taurus gas turbines burning natural gas, with fuel oil as a backup. These drive water-cooled generators to produce up to 20–24 MW of electrical power distributed throughout the campus. Gas turbine exhaust heat is used to generate up to 200,000 pounds per hour of steam in heat recovery steam generators (HRSGs). The HRSGs provide high-pressure steam to power a 4.6-MW steam turbine generator set for more electrical power and low-pressure steam for campus heating. The waste heat from the steam turbine contained in low-pressure turbine exhaust steam is combined with the HRSG low-pressure steam output for campus heating.
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Larson, E. D., and R. H. Williams. "Steam-Injected Gas Turbines." Journal of Engineering for Gas Turbines and Power 109, no. 1 (1987): 55–63. http://dx.doi.org/10.1115/1.3240006.
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Among cogeneration and central station power generating technologies, gas turbine systems are attractive largely because of their low capital cost and simplicity. However, poor part-load efficiencies have restricted simple-cycle gas turbines largely to base-load cogeneration applications, while relatively low efficiencies for the production of power only have restricted gas turbines largely to peaking central station applications. Steam-injected gas turbines overcome cogeneration part-load problems by providing for steam in excess of process requirements to be injected into the combustor to raise electrical output and generating efficiency. For central station applications, proposed steam-injected gas turbines would achieve higher efficiencies at smaller capacities than any existing commercial technology, including combined cycles. Their high efficiency and expected low capital cost would make them highly competitive for baseload power generation. This paper provides an overview of steam-injection technology, including performance calculations and an assessment of the economic significance of the technology for cogeneration and central station applications.
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Hristov, Kaloyan, and Ivan Genovski. "Influence of temperature of return district water on the performance of a backpressure steam turbine installation." IOP Conference Series: Earth and Environmental Science 1128, no. 1 (2023): 012024. http://dx.doi.org/10.1088/1755-1315/1128/1/012024.
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Abstract The district heating systems supply heat to a wide range of consumers. In the heat source of such systems, highly efficient technologies are used for the combined production of electrical and thermal energy mainly based on steam turbine installations with backpressure turbines or turbines with adjustable steam extractions. Combined production leads to a reduction in fuel consumption (fuel saving) compared to the separate production of the two energy products. The fuel saving resulting from cogeneration reduces carbon dioxide emissions. Combined production affects the amount of fuel saved, leading to a reduction in emitted emissions, both the size of the heat load realize to consumers and the temperature of the water that enters from the return pipeline of the district heating systems into the heat source. In backpressure steam turbine installations, the district water is heated by the steam that enters the boiler-condenser, and in steam turbine installations with adjustable steam extraction, it is heated in a district heater by steam extracted from the turbine. The purpose of this paper is to study the influence of the temperature of return district heating water on the performance of a backpressure steam turbine installation for cogeneration.
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., Hariyanto, Enny Rosmawar Purba, Pratiwi ., and Budi Prasetyo. "Energy Saving through Implementation and Optimization of Small and Medium Scale Cogeneration Technology." KnE Energy 2, no. 2 (2015): 94. http://dx.doi.org/10.18502/ken.v2i2.362.
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<p>Cogeneration or Combined Heat and Power (CHP) is defined as the sequential generation of two different forms of useful energy from a single primary energy source.This paper deals with a comparison study on the aspects of energy efficiency and energy economics in commercial building and industrial plant utility using conventional system and cogeneration system. This study presents the performance test result of micro turbine cogeneration application (60 kW) pilot project in comercial building and optimization of existing cogeneration system (40 MW) at utility plant of industry. The micro turbine cogeneration application for generating electricity and hot water while médium scale of gas turbine cogeneration is introduced in order to improve plant efficiency of existing steam turbine cogeneration. We found that cogeneration would be a financially viable option for building and for small and large size industrial plants. </p><p><strong>Key words</strong>: Cogeneration; energy efficiency; gas turbine; microturbine; steam turbine.</p>
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Larson, E. D., and R. H. Williams. "Biomass-Gasifier Steam-Injected Gas Turbine Cogeneration." Journal of Engineering for Gas Turbines and Power 112, no. 2 (1990): 157–63. http://dx.doi.org/10.1115/1.2906155.
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Steam injection for power and efficiency augmentation in aeroderivative gas turbines is now commercially established for natural gas-fired cogeneration. Steam-injected gas turbines fired with coal and biomass are being developed. In terms of efficiency, capital cost, and commercial viability, the most promising way to fuel steam-injected gas turbines with biomass is via the biomass-integrated gasifier/steam-injected gas turbine (BIG/STIG). The R&D effort required to commercialize the BIG/STIG is modest because it can build on extensive previous coal-integrated gasifier/gas turbine development efforts. An economic analysis of BIG/STIG cogeneration is presented here for cane sugar factories, where sugar cane residues would be the fuel. A BIG/STIG investment would be attractive for sugar producers, who could sell large quantities of electricity, or for the local electric utility, as a low-cost generating option. Worldwide, the cane sugar industry could support some 50,000 MW of BIG/STIG capacity, and there are many potential applications in the forest products and other biomass-based industries.
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Larson, E. D., T. G. Kreutz, and S. Consonni. "Combined Biomass and Black Liquor Gasifier/Gas Turbine Cogeneration at Pulp and Paper Mills." Journal of Engineering for Gas Turbines and Power 121, no. 3 (1999): 394–400. http://dx.doi.org/10.1115/1.2818486.
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Kraft pulp and paper mills generate large quantities of black liquor and byproduct biomass suitable for gasification. These fuels are used today for onsite cogeneration of heat and power in boiler/steam turbine systems. Gasification technologies under development would enable these fuels to be used in gas turbines. This paper reports results of detailed full-load performance modeling of pulp-mill cogeneration systems, based on gasifier/gas turbine technologies and, for comparison, on conventional steam-turbine cogeneration technologies. Pressurized, oxygen-blown black liquor gasification, the most advanced of proposed commercial black liquor gasifier designs, is considered, together with three alternative biomass gasifier designs under commercial development (high-pressure air-blown, low-pressure air-blown, and low-pressure indirectly-heated). Heavy-duty industrial gas turbines of the 70-MWe and 25-MWe class are included in the analysis. Results indicate that gasification-based cogeneration with biomass-derived fuels would transform a typical pulp mill into a significant power exporter and would also offer possibilities for net reductions in emissions of carbon dioxide relative to present practice.
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Law, B., and B. V. Reddy. "EFFECT OF OPERATING VARIABLES ON THE PERFORMANCE OF A COMBINED CYCLE COGENERATION SYSTEM WITH MULTIPLE PROCESS HEATERS." Transactions of the Canadian Society for Mechanical Engineering 33, no. 1 (2009): 65–74. http://dx.doi.org/10.1139/tcsme-2009-0007.
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Combined cycle power plants with a gas turbine topping cycle and a steam turbine bottoming cycle are widely used due to their high efficiencies. Combined cycle cogeneration has the possibility to produce power and process heat more efficiently, leading to higher performance and reduced green house gas emissions. The objective of the present work is to analyze and simulate a natural gas fired combined cycle cogeneration unit with multiple process heaters and to investigate the effect of operating variables on the performance. The operating conditions investigated include, gas turbine pressure ratio, process heat loads and process steam extraction pressure. The gas turbine pressure ratio significantly influences the performance of the combined cycle cogeneration system. It is also identified that extracting process steam at lower pressures improves the power generation and cogeneration efficiencies. The process heat load influences combined cycle efficiency and combined cycle cogeneration efficiency in opposite ways. It is also observed that using multiple process heaters with different process steam pressures, rather than a single process heater, improves the combined cycle cogeneration plant efficiency.
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Stepanova, Elena, and Alexey Maksimov. "Influence of inter nal relative efficiency of steam turbine compartments on the performance of steam turbine cogeneration plant." E3S Web of Conferences 69 (2018): 02006. http://dx.doi.org/10.1051/e3sconf/20186902006.
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The paper considers a steam turbine cogeneration plant that includes a back-pressure steam turbine and a natural gas-fired steam boiler that enables exhaust gas heat recovery, which is rather promising for the isolated heat and electricity consumers. A design and verification mathematical model of the steam turbine plant was developed. The focus is made on the optimization studies into the effect of the relative efficiency of turbine compartments on the performance indices of the steam turbine cogeneration plant with an installed electric capacity of 50 MW that uses the heat of steam contained in the combustion products of the boiler for heating the feed-water of the heat network.
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HATEM, FALAH F. "Using Alternative Cogeneration Plants in Iraqi Petroleum Industry." Journal of Engineering 20, no. 12 (2023): 117–31. http://dx.doi.org/10.31026/j.eng.2014.12.08.
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The present paper describes and analyses three proposed cogeneration plants include back pressure steam-turbine system, gas turbine system, diesel-engine system, and the present Dura refinery plant. Selected actual operating data are employed for analysis. The same amount of electrical and thermal product outputs is considered for all systems to facilitate comparisons. The theoretical analysis was done according to 1st and 2nd law of thermodynamic. The results demonstrate that exergy analysis is a useful tool in performance analysis of cogeneration systems and permits meaningful comparisons of different cogeneration systems based on their merits, also the result showed that the back pressure steam-turbine is more efficient than other proposals. Moreover, the results of the present work indicate that these alternative plants can produce more electric power than that required in the refinery. At present time, the industrial cogeneration plants are recommended in Iraq, especially in petroleum industry sectors, in order to contribute with ministry of electricity to solve the present crisis of electric power generation. Such excess in the power can sold to the main electric network. The economic analysis are proved the feasibility of the proposed cogeneration plants with payback period of four year and six months ,three year and eight months, and ten years for steam cogeneration plant, gas turbine cogeneration plant and diesel engine cogeneration plant respectively.
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Strusnik, Dusan, Igor Kustrin, and Jurij Avsec. "Off-design flow analysis of cogeneration steam turbine with real process data." Thermal Science 26, no. 5 Part B (2022): 4107–17. http://dx.doi.org/10.2298/tsci2205107s.
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This paper presents the concept of reconstruction of the existing coal-fired combined heat and power plant to comply with new European environmental policies. The existing coal-fired boiler will be replaced by two new dual pressure heat recovery steam generators, which will utilize the exhaust gas heat from two new gas turbines. The steam from the heat recovery steam generators will be fed to the existing steam turbine. After the reconstruction, the nominal turbine inlet steam mass-flow of 40 kg/s will be reduced to 30 kg/s. During periods of low heat demand, only one gas turbine and one heat recovery steam generator will be in operation and the live steam mass-flow may drop even to 12 kg/s. Prior to the reconstruction, dedicated tests of the existing steam turbine were carried out using the steam from the existing coal-fired boiler. The goal of the test was to verify the viability of operation with such an extremely low mass-flow. The results of tests show that such operation is possible but inefficient from a power generation point of view. Besides this, the turbine control algorithm needs to be accommodated to this extreme operating regime and additional measures like displacement of the extraction points and steam cooling will be required to control the temperature of the steam extractions. The novelty of this paper is using real pre-reconstruction process data for the assessment of feasibility and efficiency of the post-reconstruction operation of a combined heat and power turbine.
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Grkovic, Vojin, Dragoljub Zivkovic, and Milana Gutesa. "A new approach in CHP steam turbines thermodynamic cycles computations." Thermal Science 16, suppl. 2 (2012): 399–407. http://dx.doi.org/10.2298/tsci120503178g.
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This paper presents a new approach in mathematical modeling of thermodynamic cycles and electric power of utility district-heating and cogeneration steam turbines. The approach is based on the application of the dimensionless mass flows, which describe the thermodynamic cycle of a combined heat and power steam turbine. The mass flows are calculated relative to the mass flow to low pressure turbine. The procedure introduces the extraction mass flow load parameter ?h which clearly indicates the energy transformation process, as well as the cogeneration turbine design features, but also its fitness for the electrical energy system requirements. The presented approach allows fast computations, as well as direct calculation of the selected energy efficiency indicators. The approach is exemplified with the calculation results of the district heat power to electric power ratio, as well as the cycle efficiency, versus ?h. The influence of ?h on the conformity of a combined heat and power turbine to the grid requirements is also analyzed and discussed.
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Hristov, Kaloyan. "MODELING OF THE ENERGY EFFICIENCY OF CHP STEAM TURBINE INSTALLATIONS." Вестник КазАТК 119, no. 4 (2021): 94–100. http://dx.doi.org/10.52167/1609-1817-2021-119-4-94-100.
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District heat supply systems satisfy the heat needs of a wide range of consumers. The combined heat and power (CHP) installations are based mainly on steam turbine installations. The energy efficiency of steam turbine installations is influenced by the heat released into the system, the temperature of the district water at the outlet of the district heater and the temperature of the district water returned from the district heating system. This report aims to present an approach to assess the energy efficiency of cogeneration from steam turbines using mathematical and simulation modeling.
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O'Brien, J. M., and P. K. Bansal. "Modelling of cogeneration systems. Part 2: Development of a quasi-static cogeneration model (steam turbine cogeneration analysis)." Proceedings of the Institution of Mechanical Engineers, Part A: Journal of Power and Energy 214, no. 2 (2000): 125–43. http://dx.doi.org/10.1243/0957650001538236.
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Steam turbine cogeneration analysis (STuCA) is a quasi-static cogeneration plant model that has been developed to simulate steam turbine cogeneration plants subject to varying loads. STuCA was developed to provide potential cogeneration plant users with a model that could simulate part-load performance over the expected operating range of the cogeneration plant using fundamental engineering analysis methods. The model was designed to bridge the gap between static design-point models that could not accommodate part-load conditions and complex part-load models which are too expensive for small scale cogeneration proposals. In addition, the model contains economic analysis tools to analyse the thermoeconomic performance of the plant and to conduct a cash flow analysis. These features are an extension to the static and part-load models. The model consists of four submodels: a load, system, plant and economic model. The load submodel drives the cogeneration plant simulation, supplying utility demands to the system models. The system submodels calculate the steam required by the system components to meet the utility demands. The plant submodel then predicts turbine and boiler performance as they meet the steam demand. The primary plant submodel outputs are the electricity generated and quantity of coal consumed by the boiler, which are used by the economic submodel to conduct a thermoeconomic analysis of the site as well as a discounted cash flow analysis. This method of modelling results in a model that can predict plant performance with respect to varying load and then use those data to conduct a meaningful economic performance analysis of the site.
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Elhaj, Mohamed A., Jamal S. Yassin, and Ali E. Hegaig. "Thermodynamic Feasibility of Cogeneration Gas/Steam Combined Cycle." Advanced Materials Research 658 (January 2013): 425–29. http://dx.doi.org/10.4028/www.scientific.net/amr.658.425.
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This paper is to investigate the thermodynamic feasibility of cogeneration gas/steam combined cycle, in which a computer program, called “Cogeneration Design" has been developed using MATLAB (v7.8) for the analysis. In this cycle one can take advantage of the thermal energy to produce steam which can be used in some small and medium-sized factories such as dairy , juice, soap, paper factories, as well as in desalination plants and other industrial applications need hot water or steam. Here, the thermodynamic analysis is carried out according to three cases, (1)non condensing steam turbine, (2) condensing steam turbine, (3)extraction condensing steam turbine. The results obtained show a difference between the three studied cases, in which the overall efficiency is the highest for case (1), equal 52.82 %, then for case (3), equal 49.13 %, then for case (2), equal 45.31 %.
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Habib, M. A. "First- and Second-Law Analysis of Steam-Turbine Cogeneration Systems." Journal of Engineering for Gas Turbines and Power 116, no. 1 (1994): 15–19. http://dx.doi.org/10.1115/1.2906786.
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The paper presents an analysis of a cogeneration plant. The performance of the plant is compared to a conventional plant with separate production of process heat and power. The analysis is first- and second-law based and, therefore, quantifies the irreversibilities of the different components of each plant. In the cogeneration plant, the heat required in the boiler can be obtained either from fuel firing (condensing or back-pressure turbine plant) or from exhaust gases of a simple gas turbine (gas turbine cogeneration plant). The present study compares the two methods. The influence of the heat-to-power ratio and the process pressure on the thermal efficiency, utilization factor, and irreversibilities of the different components of each plant is presented. The results show that the total irreversibility of the cogeneration plant is lower by 38 percent compared to the conventional plant. This reduction in the irreversibility is accompanied by an increase in the thermal efficiency and utilization factor by 25 and 24 percent, respectively. The results show that most irreversible losses are due to boiler.
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Huang, F. F. "Performance Evaluation of Selected Combustion Gas Turbine Cogeneration Systems Based on First and Second-Law Analysis." Journal of Engineering for Gas Turbines and Power 112, no. 1 (1990): 117–21. http://dx.doi.org/10.1115/1.2906465.
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The thermodynamic performance of selected combustion gas turbine cogeneration systems has been studied based on first-law as well as second-law analysis. The effects of the pinch point used in the design of the heat recovery steam generator, and pressure of process steam on fuel-utilization efficiency (first-law efficiency), power-to-heat ratio, and second-law efficiency, are examined. Results for three systems using state-of-the-art industrial gas turbines show clearly that performance evaluation based on first-law efficiency alone is inadequate. Decision makers should find the methodology contained in this paper useful in the comparison and selection of cogeneration systems.
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Burdenkova, Elena, and Michael Garievsky. "Optimization of schemes and ways to expand the adjustment range for the power supply of combined heat and power plants." E3S Web of Conferences 461 (2023): 01042. http://dx.doi.org/10.1051/e3sconf/202346101042.
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The article assesses the possibility of using low-flow operating modes at steam turbine with an additional boiler and steam and combined-cycle cogeneration plants for heat supply schemes, taking into account the storage properties of heat networks and buildings. It is shown that the use of low-flow operation modes of the turbine plant during the night period allows the combined heat and power plant to participate more effectively in covering the variable part of the electric load schedule. The dependence of the share of participation of an additional boiler in covering the heat load on the prices for fuel and electricity is determined. Comparison of the performance indicators of the steam turbine CHPP in low-flow modes with the release of the thermal energy necessary to the consumer from an additional boiler with the mode of its complete shutdown and the release of thermal energy from the peak hot water boiler made it possible, taking into account the accumulating properties of heat networks and buildings, to recommend a low-flow operation mode at night. For a combined-cycle cogeneration plant it is shown that it is advisable to reduce the electric power at night, while ensuring the nominal heat supply, by unloading the gas turbines with the transfer of the steam turbine to the motor mode.
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Gonçalves, L. P., and F. R. P. Arrieta. "AN EXERGY COST ANALYSIS OF A COGENERATION PLANT." Revista de Engenharia Térmica 9, no. 1-2 (2010): 28. http://dx.doi.org/10.5380/reterm.v9i1-2.61927.
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The exergy analysis, including the calculation of the unit exergetic cost of all flows of the cogeneration plant, was the main purpose of the thermoeconomic analysis of the STAG (STeam And Gas) combined cycle CHP (Combined Heat and Power) plant. The combined cycle cogeneration plant is composed of a GE10 gas turbine (11250 kW) coupled with a HRSG (Heat Recovery Steam Generator) and a condensing extraction steam turbine. The GateCycleTM Software was used for the modeling and simulation of the combined cycle CHP plant thermal scheme, and calculation of the thermodynamic properties of each flow (Mass Flow, Pressure, Temperature, Enthalpy). The entropy values for water and steam were obtained from the Steam Tab software while the entropy and exergy of the exhaust gases were calculated as instructed by. For the calculation of the unit exergetic cost was used the neguentropy and Structural Theory of Thermoeconomic. The GateCycleTM calculations results were exported to an Excel sheet to carry out the exergy analysis and the unit exergetic cost calculations with the thermoeconomic model that was created for matrix inversion solution. Several simulations were performed varying separately five important parameters: the Steam turbine exhaust pressure, the evaporator pinch point temperature, the steam turbine inlet temperature, Rankine cycle operating pressure and the stack gas temperature to determine their impact in the recovery cycle heat exchangers transfer area, power generation and unit exergetic cost.
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Bubnov, K. N., V. P. Zhukov, A. V. Golubev, E. V. Barochkin, and S. I. Shuvalov. "System for continuous monitoring of technical condition and maintenance diagnostics of steam turbine." Vestnik IGEU, no. 4 (August 31, 2023): 85–93. http://dx.doi.org/10.17588/2072-2672.2023.4.085-093.
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Power equipment deterioration occurs during operation, it causes loss in reliability and efficiency, unscheduled shutdowns, and accidents. Now predictive analytics is one of the promising directions in the field of power engineering which allows to control and analyze the technical condition of power equipment. The problems of localization of deviation of technological parameters and detection of anomaly in the operation of power equipment are consistently solved in the framework of predictive analytics. The problems of deviations localization and anomalies detection are solved by the methods of statistical modeling and the classification algorithms respectively. However, for steam turbines the localization of deviation and the detection of anomalies having slow-flowing character are a difficult problem. Therefore, the issue of development of a method for continuous monitoring of technical condition and maintenance diagnostics based on a mathematical model of the steam turbine section flow characteristics is worth noticing. The method allows us to consider the effect of changes in the open flow area of the individual sections of a steam turbine on the pressure distribution over the steam flow path. The model of a steam turbine has been developed within the matrix formalization methodology. The solution of the system of linear and nonlinear equations is carried out by methods of computational mathematics. The solution of the optimization problems of the steam flow path diagnostics is carried out by methods of mathematical programming. A mathematical model of the cogeneration steam turbine Т-250/305-23.5-DB and a method for continuous condition monitoring and maintenance diagnostics of steam turbine have been developed. It allows us to localize deviation and detect anomaly by recovery of the open flow area of the individual sections of a steam turbine based on the pressure distribution over the steam flow path. The results of the statistical analysis prove that a mathematical model of the cogeneration steam turbine Т-250/305-23.5-DB has been recognized adequate. The method for continuous condition monitoring and maintenance diagnostics of steam turbine has demonstrated consistency of the obtained results and ability to solve diagnostic problems in practice. The developed model and method can be used as a module in the development of a software package for predictive analytics of power equipment.
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Nguyen, H. B., and A. den Otter. "Development of Gas Turbine Steam Injection Water Recovery (SIWR) System." Journal of Engineering for Gas Turbines and Power 116, no. 1 (1994): 68–74. http://dx.doi.org/10.1115/1.2906811.
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This paper describes and discusses a “closed-loop” steam injection water recovery (SIWR) cycle that was developed for steam-injected gas turbine applications. This process is needed to support gas turbine steam injection especially in areas where water cannot be wasted and complex water treatment is discouraged. The development of the SIWR was initiated by NOVA in an effort to reduce the environmental impact of operating gas turbines and to find suitable solutions for its expanding gas transmission system to meet future air emission restrictions. While turbine steam injection provides many benefits, it has not been considered for remote, less supported environments such as gas transmission applications due to its high water consumption. The SIWR process can alleviate this problem regardless of the amount of injection required. The paper also covers conceptual designs of a prototype SIWR system on a small gas turbine unit. However, because of relatively high costs, it is generally believed that the system is more attractive to larger size turbines and especially when it is used in conjunction with cogeneration or combined cycle applications.
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Arteaga Linzan, Angel Rafael, Ángel Luis Brito Sauvanell, Manuel Ángel Cantos Macías, and Enrique Gilbert. "Selección del esquema de cogeneración para una industria de pescado enlatado. Caso Ecuador." Revista de Investigaciones en Energía, Medio Ambiente y Tecnología: RIEMAT ISSN: 2588-0721 1, no. 2 (2016): 34. http://dx.doi.org/10.33936/riemat.v1i2.926.
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The determination of the parameter β=1.868 (the ratio of heat output (Q=4,771x109 kJ\mes) and electricity consumed (W=2,549x109 kJ\mes) by the industry) was per-formed selection of more suitable cogeneration scheme for its application in the conditions of a fish canning industry. Considering that the proposed cogeneration scheme would represent a savings in US dollars for the company as well as the fuel subsidy and various economic and environmental points of view, were calculated, the time of amortization for several cogeneration schemes with steam Turbines (TV= 20,89 years), with gas turbines (TG= 3,16 years) and with internal diesel combustion engines (MCID= 2,72 years) concluding that as the first alternatives to be considered are internal combustion engines and gas turbines. Whereas thermal energy of the internal diesel combustion engine is very disjointed, and fish canning industry need steam parameters from 0.8 to 1.3 bar absolute so the tons of CO2 not-emitted to the atmosphere by the use of this technology (TV= 2137, TG= 4490 y IDCE= 4987), it was concluded that the cogeneration scheme with gas turbine is the most viable technology ecological and economically for this type of industry. 
 Index Terms Cogeneration, rate heat and power, repayment period, β parameter, fuel savings.
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Zaryankin, Arkadiy, Alexander Akatov, Ivan Lavyrev, and Mikhail Cherkasov. "On the rational form of rotary control diaphragms for steam turbines with industrial and cogeneration steam extraction." MATEC Web of Conferences 345 (2021): 00019. http://dx.doi.org/10.1051/matecconf/202134500019.
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The Russian park of power steam turbines contains a large number of turbines with adjustable steam extraction from the flow path where rotary control diaphragms are used as flow controllers, which structurally easily fit into the flow path of these turbines. This method of regulating the steam flow rate is accompanied by a decrease in the efficiency of the subsequent stages of the turbine and causes the appearance, at reduced loads, of additional disturbing forces acting on the rotor blades. In the presented materials, a variant of a post-sampling stage with a radial rotary control diaphragm is considered. The performed mathematical modeling of the working fluid flows in such a stage showed that in this case, at all turbine loads, a relatively uniform velocity field is provided when steam enters the nozzle apparatus, which naturally entails the elimination of the noted drawbacks.
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Shavdinova, M. D. "ENHANCEMENT OF STEAM-TURBINE CONDENSER STEAM-JET EJECTOR." Eurasian Physical Technical Journal 18, no. 4 (38) (2021): 52–58. http://dx.doi.org/10.31489/2021no4/52-58.
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A three-stage steam-jet ejector EPO-3-200 with a working steam flow rate of 850 t / h is installed at the Combined Heat and Power Plant-2 of the city of Almaty on heating turbines. In this paper, the replacement of the existing three-stage steam-jet ejector with a two-stage steam-jet ejector is proposed and substantiated. As a result of the replacement, they obtained a saving of heat (steam) for their own needs for the production of electrical energy. It has been established that at a pressure in the turbine condenser significantly lower than 100 kPa, it is advisable to install a new two-stage ejector EPO-2-80 instead of EPO-3-200. Using the existing calculation methods, the geometric characteristics of the new ejector were obtained. The working steam flow rate of the new two-stage ejector is 579 t / h. In addition, the use of two stages makes it possible to simplify the design and make it more reliable, and also makes it possible to increase the pressure in the cooler of the 1st stage of the ejector. This is especially important for cogeneration turbines, which may have a high temperature of the main condensate, which adversely affects the performance of a conventional three-stage ejector.
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Genovski, Ivan, and Kaloyan Hristov. "Model research of the energy efficiency of a cogeneration backpressure steam turbine installation." E3S Web of Conferences 207 (2020): 02004. http://dx.doi.org/10.1051/e3sconf/202020702004.
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In the contemporary district heating systems (DHS) heat energy for the customers is generated by cogeneration method, which leads to the saving of primary energy resources compared to the separate production method. The most widespread technology for combined production is based on steam turbine installations with adjustable steam extraction and backpressure steam turbine. In these technologies district heating water is heated to the required temperature either in district heaters in case of steam turbine with adjustable steam extractions or in boiler-condenser in case of backpressure steam turbine installations. The temperature of the district heat water at the inlet of the CHP installation depends on the mode of operation of the DHS. The heat load, distributed to consumers, is regulated at the heat source (CHP installation) by temperature and flow rate of the district heating water, mainly following the change in climatic factors. Current study presents the development of a simulation model of existing CHP backpressure steam turbine. The object studied is a backpressure steam turbine type SST-300 CE2L/V36S. Presented are results from the validation of the simulated model with data from the design documentation. The model has been used to study the energy efficiency of a steam turbine installation based on multivariate simulation calculations. The results obtained relate the energy efficiency indicators of CHP backpressure steam turbine with the factors that characterize the mode of operation of the district heating system.
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Ito, K., R. Yokoyama, and Y. Matsumoto. "Optimal Operation of Cogeneration Plants With Steam-Injected Gas Turbines." Journal of Engineering for Gas Turbines and Power 117, no. 1 (1995): 60–66. http://dx.doi.org/10.1115/1.2812782.
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The effect of introducing steam-injected gas turbines into cogeneration plants is investigated from economical and energy-saving aspects on the basis of a mathematical programming approach. An optimal planning method is first presented by which the operational strategy is assessed so as to minimize the hourly running cost. Then, a case study is carried out on a plant used for district heating and cooling. Through the study, it is ascertained that the proposed method is a useful tool for the operational planning of steam-injected gas turbine plants, and that these plants can be attractive from economical and energy-saving viewpoints as compared with both simple-cycle gas turbine plus waste heat boiler plants and conventional energy supply ones.
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Chantasiriwan, Somchart. "Increased Energy Efficiency of a Backward-Feed Multiple-Effect Evaporator Compared with a Forward-Feed Multiple-Effect Evaporator in the Cogeneration System of a Sugar Factory." Processes 8, no. 3 (2020): 342. http://dx.doi.org/10.3390/pr8030342.
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The cogeneration system of a sugar factory consists of boiler, steam turbine, and sugar juice evaporation process. The multiple-effect evaporator used for the conventional sugar juice evaporation process is the forward-feed multiple-effect evaporator, in which steam and sugar juice flow in the same direction. The main objective of this paper is to investigate the energy efficiency of the backward-feed multiple-effect evaporator, in which steam and sugar juice flow in opposite directions, compared with that of the forward-feed multiple-effect evaporator. Mathematical models are developed for both multiple-effect evaporators, and used to compare the performances of two cogeneration systems that use the forward-feed and backward-feed multiple-effect evaporators. The forward-feed multiple-effect evaporator requires extracted steam from a turbine at one pressure, whereas the backward-feed multiple-effect evaporator requires steam extraction at two pressures. Both evaporators have the same total heating surface area, process the same amount of sugar juice, and operate at the optimum conditions. It is shown that the cogeneration system that uses the backward-feed multiple-effect is more energy efficient than the cogeneration system that uses the forward-feed multiple-effect because it yields more power output for the same fuel consumption.
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Ning, Zhe, Wenping Ju, Bo Hu, et al. "A thermodynamic analysis of optimization schemes for a heat-power cogeneration system." High Temperatures-High Pressures 49, no. 5-6 (2020): 369–81. http://dx.doi.org/10.32908/hthp.v49.913.
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To overcome the strong thermoelectric coupling in a coal-fired combined heat and power plant (CCHPT), three optimization schemes are investigated. These include low-pressure turbine little steam operation (LLPEH), extracting steam from high pressure turbine (HP-LPEH), and integrating the LLPEH and HP-LPEH (HP-LLPEH). These are employed for enhancing the plant�s heat and electricity supply flexibility using steam extracted between the intermediate- and low-pressure turbines to provide heat (LPEH). The thermodynamic and economic performance of the schemes when applied to a 330MW coal-fired combined heat and power plant were evaluated and compared. The comparison reveals the highest heat supply capacity, highest heat to electricity ratio, and lowest standard coal consumption for the HP-LLPEH scheme, while the LPEH exhibits the highest thermal efficiency.
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Eidensten, L., J. Yan, and G. Svedberg. "Biomass Externally Fired Gas Turbine Cogeneration." Journal of Engineering for Gas Turbines and Power 118, no. 3 (1996): 604–9. http://dx.doi.org/10.1115/1.2816691.
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This paper is a presentation of a systematic study on externally fired gas turbine cogeneration fueled by biomass. The gas turbine is coupled in series with a biomass combustion furnace in which the gas turbine exhaust is used to support combustion. Three cogeneration systems have been simulated. They are systems without a gas turbine, with a non-top-fired gas turbine, and a top-fired gas turbine. For all systems, three types of combustion equipment have been selected: circulating fluidized bed (CFB) boiler, grate fired steam boiler, and grate fired hot water boiler. The sizes of biomass furnaces have been chosen as 20 MW and 100 MW fuel inputs. The total efficiencies based on electricity plus process heat, electrical efficiencies, and the power-to-heat ratios for various alternatives have been calculated. For each of the cogeneration systems, part-load performance with varying biomass fuel input is presented. Systems with CFB boilers have a higher total efficiency and electrical efficiency than other systems when a top-fired gas turbine is added. However, the systems with grate fired steam boilers allow higher combustion temperature in the furnace than CFB boilers do. Therefore, a top combustor may not be needed when high temperature is already available. Only one low-grade fuel system is then needed and the gas turbine can operate with a very clean working medium.
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Radu-Cristian, Dinu, Stan-Ivan Felicia-Elena, and Buzatu Gabriel-Cosmin. "Comparative Analysis Concerning the Use of the Thermal Potential of Combustion Gases in Industrial Cogeneration Systems." Annals of the University of Craiova Electrical Engineering Series 48 (January 23, 2025): 87–92. https://doi.org/10.52846/aucee.2024.13.
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Cogeneration is defined as the process of simultaneous production of heat and electricity, with the same installation (heat engine-electric generator group, turbine, etc.). Unlike classic Thermal Power Plants, cogeneration plants can be sized in correlation with the thermal energy requirement, which means that electricity is considered a "secondary" product. Throughout the article, taking into account the general theoretical aspects of the definition and operation of cogeneration systems, through the prism of specific energy indicators, the results obtained in the case of the implementation of a cogeneration system that uses the energy potential of gases are studied of combustion, for the production of the thermal agent for heating and preparation of hot water for consumption. of steam. From a functional point of view, at the level of a refinery, three superheated steam networks are needed, corresponding to three different pressure domains, which means that the results obtained in the study as the case may be, to refer to three distinct modes of operation of the cogeneration system. The main purpose of the operation of such a system for the combined production of electrical and thermal energy is to obtain as much energy as possible in the form of mechanical work by expanding steam in the turbines.
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Foster-Pegg, R. W. "A Small Air Turbine Power Plant Fired With Coal in an Atmospheric Fluid Bed." Journal of Engineering for Gas Turbines and Power 112, no. 1 (1990): 21–27. http://dx.doi.org/10.1115/1.2906472.
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An efficient, indirectly heated, steam-injected air turbine power or cogeneration plant, fired with coal in an atmospheric fluid bed, is described. The plant will meet all environmental standards and will generate about 35 MW. The plant offers a high power-to-steam ratio without requiring a condensing steam turbine and can operate efficiently without any export steam. Eliminating a condensing steam turbine, cooling tower, etc., reduces the capital cost and produces a low $/kW installation. If necessary, most of the water injected into the air turbine can be recovered from the exhaust air and reused. All the equipment for the plant is commercially available.
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Siqueira, Abilio Teixeira de, Edson Bazzo, Pedro Lo Giudice, and Eduardo Burin. "Biomass cogeneration plants integrated into poultry slaughterhouses for reducing industry costs with energy." Acta Scientiarum. Technology 43 (February 26, 2021): e50967. http://dx.doi.org/10.4025/actascitechnol.v43i1.50967.
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A technical and economic feasibility analysis was performed concerning biomass cogeneration to supply the thermal and electricity demands of poultry slaughterhouses. The analysis considers measured data referring to the annual energy consumption from an existing industry as well as the characteristics of equipment available in the Brazilian market. The cogeneration plant is equipped with a water tube steam generator and a condensing-extraction steam turbine in a Rankine cycle. Four different configurations were evaluated, including impulse and reaction turbines at two steam pressure/temperature levels (43 bar / 450 °C and 68 bar / 520 °C). A steady state full load operation is considered at cogeneration mode on the weekdays and at Rankine power plant mode on the weekends, when there is no process steam consumption. The technical analysis pointed out the reaction turbine at 68 bar / 520 ºC as the best alternative, leading to the highest overall efficiency. In addition, this plant configuration showed economic advantages represented by an Internal Rate of Return (IRR) of 21%, a Net Present Value (NPV) of US$ 10.93 million, and a payback time of 6 years, enabling a reduction on the industrial cost with energy in the slaughterhouse to 19 US$/ton of product (-30% in comparison to the base case). Finally, the calculated LCOE of 73 US$/MWh was lower than the current price of the electricity in the market, indicating potential economic feasibility of the proposed concept.
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Shubenko, Oleksandr, Volodymyr Goloshchapov, Olga Kotulska, Tetyana Paramonova, and Daria Senetska. "THERMAL STATE OF THE LOW-PRESSURE CYLINDER WORKING BLADES OF THE COGENERATION TURBINE T-250/300-240." Bulletin of the National Technical University "KhPI". Series: Hydraulic machines and hydraulic units, no. 1 (October 10, 2023): 18–24. http://dx.doi.org/10.20998/2411-3441.2023.1.03.
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The important problem of researching the temperature state of the low-pressure cylinder of a powerful cogeneration turbine, which works, unlike condensing turbines, in conditions of significant changes in electrical and thermal load, is considered. This is since the low-pressure cylinder of the cogeneration turbines in the heating season operates at the low-flow rate modes due to the large selection of steam for heating. Such operating conditions are accompanied by the nucleation of vortex structures in the flow path, which leads to a significant increase in mechanical energy losses and, consequently, to an increase in the temperature of the elements of the flow path. The aim of the study is to determine the thermal state of the steam in a wide range of changes in the operation modes of the cogeneration turbine. The analysis of the results of experimental studies obtained on full-scale low-pressure cylinders of a powerful T-250/300-240 steam turbine by various authors in conditions of wide changes in operating parameters (the pressure in the condenser, the steam consumption in the flow path, the temperature of the lower heating selection) was performed. This made it possible to determine the temperature distribution along the height of the working blade of the last stage, which is of the greatest interest in the conditions of operation at the low-flow rate modes. The location of the minimum temperature is established, and a dependence is proposed for its determination at the exit from the working wheel of the stage, considering that the main generator of heat during steam heating is a rotating vortex in the rim clearance. It is shown that the limiting value of steam consumption through the last stage, which corresponds to the transition of the flow from the area of wet steam to the area of superheated steam, at a given temperature level in the lower heating selection, depends on the pressure in the condenser and can be determined as a function of these parameters. At the same time, with a decrease in the temperature in the lower heating selection and the pressure in the condenser, it will lead to the fact that the transition from the west steam to the superheated steam is observed at lower consumption. The increase of process moisture at the outlet of the working wheel occurs when the steam flow is greater than its limiting value.
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Larson, Eric D., Stefano Consonni, and Thomas G. Kreutz. "Preliminary Economics of Black Liquor Gasifier/Gas Turbine Cogeneration at Pulp and Paper Mills." Journal of Engineering for Gas Turbines and Power 122, no. 2 (2000): 255–61. http://dx.doi.org/10.1115/1.483203.
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Black liquor, the lignin-rich byproduct of kraft pulp production, is burned in boiler/steam turbine cogeneration systems at pulp mills today to provide heat and power for onsite use. Black liquor gasification technologies under development would enable this fuel to be used in gas turbines. This paper reports preliminary economics of 100-MWe scale integrated black-liquor gasifier/combined cycles using alternative commercially proposed gasifier designs. The economics are based on detailed full-load performance modeling and on capital, operating and maintenance costs developed in collaboration with engineers at Bechtel Corporation and Stone & Webster Engineering. Comparisons with conventional boiler/steam turbine systems are included. [S0742-4795(00)00402-6]
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Bee´r, J. M., and R. V. Garland. "A Coal-Fueled Combustion Turbine Cogeneration System With Topping Combustion." Journal of Engineering for Gas Turbines and Power 119, no. 1 (1997): 84–92. http://dx.doi.org/10.1115/1.2815567.
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Cogeneration systems fired with coal or other solid fuels and containing conventional extracting-condensing or back pressure steam turbines can be found throughout the world. A potentially more economical plant of higher output per unit thermal energy is presented that employs a pressurized fluidized bed (PFB) and coal carbonizer. The carbonizer produces a char that is fed to the PFB and a low heating value fuel gas that is utilized in a topping combustion system. The topping combustor provides the means for achieving state-of-the-art turbine inlet temperatures and is the main contributor to enhancing the plant performance. An alternative to this fully coal-fired system is the partially coal, partially natural gas-fired air heater topping combustion cycle. In this cycle compressed air is preheated in an atmospheric pressure coal-fired boiler and its temperature raised further by burning natural gas in a topping gas turbine combustor. The coal fired boiler also generates steam for use in a cogeneration combined cycle. The conceptual design of the combustion turbine is presented with special emphasis on the low-emissions multiannular swirl burner topping combustion system and its special requirements and features.
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Chantasiriwan, Somchart. "Modification of Conventional Sugar Juice Evaporation Process for Increasing Energy Efficiency and Decreasing Sucrose Inversion Loss." Processes 8, no. 7 (2020): 765. http://dx.doi.org/10.3390/pr8070765.
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The evaporation process, boiler, and turbine are the main components of the cogeneration system of the sugar factory. In the conventional process, the evaporator requires extracted steam from the turbine, and bled vapor from the evaporator is supplied to the juice heater and the pan stage. The evaporation process may be modified by using extracted steam for the heating duty in the pan stage. This paper is aimed at the investigation of the effects of this process modification. Mathematical models of the conventional and modified processes were developed for this purpose. It was found that, under the conditions that the total evaporator area is 13,000 m2, and the inlet juice flow rate is 125 kg/s, the optimum modified evaporation process requires extracted steam at a pressure of 157.0 kPa. Under the condition that the fuel consumption rate is 21 kg/s, the cogeneration system that uses the optimum modified evaporation process yields 2.3% more power output than the cogeneration system that uses a non-optimum conventional cogeneration process. Furthermore, sugar inversion loss of the optimum modified process is found to be 63% lower than that of the non-optimum conventional process.
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Kumar, PV Ram, and S. S. Kachhwaha. "Thermodynamic Performance Evaluation of Alternative Regeneration Gas Turbine Cogeneration Cycle with Two Shaft System." International Journal of Advance Research and Innovation 2, no. 2 (2014): 193–202. http://dx.doi.org/10.51976/ijari.221426.
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This paper presents thermodynamic performance evaluation of gas turbine co-generation with alternative regeneration system in comparison to simple and conventional regenerative cogeneration systems. The energetic and exergetic efficiencies have been defined. The effects of pinch point temperature (PPT) and process steam pressure used in have been investigated. For higher TITs the second law efficiency and power to heat ratio is relatively higher for alternative regeneration with cogeneration system. It is observed from the results obtained that power to heat ratio increases with increase in pinch point but first and second law efficiency decreases with an increase in pinch point. Power to heat ratio increases significantly with increase in process steam pressure but first law efficiency decreases with the same. The second law efficiency increases with increase in process steam pressure up to 1 MPa and afterwards decreases with increase in process steam pressure. Results also show that inclusion of cogeneration with alternate regeneration provides significant improvement in process heat production and second law efficiency.
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Enyi, C. G., and D. Appah. "Maximizing Generated Energy Usage through Combined Cycle Cogeneration." Advanced Materials Research 62-64 (February 2009): 415–19. http://dx.doi.org/10.4028/www.scientific.net/amr.62-64.415.
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Case studies from two Nigerian hydrocarbon processing industries, where gas turbine generators (GTG) were used for power generation were analyzed. The first study analyzed a simple cycle power generation where the GTG produced 25 MW of electricity and three separately fired boilers produced the required process steam. The second study analyzed a combined cycle (cogeneration) where the same GTG that produced 25 MW of electricity also generated 90700 Kg/hr of steam from the turbine exhaust gas. The study shows that cogeneration (combined cycle) satisfied all the electric power and steam requirements of the plant. Simple cycle only satisfied the electric power requirement. Other disadvantages of simple cycle show that over 60% of the generated energy is lost to the environment in form of heat. A loss in production worth over $6,182,400 as a result of failure in a separately fired boiler was calculated. The study concludes that cogeneration must be undertaken with an awareness of energy system expansion, generation costs and the need for industrial energy consumption of a given plant.
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Bhargava, R., and A. Peretto. "A Unique Approach for Thermoeconomic Optimization of an Intercooled, Reheat, and Recuperated Gas Turbine for Cogeneration Applications." Journal of Engineering for Gas Turbines and Power 124, no. 4 (2002): 881–91. http://dx.doi.org/10.1115/1.1476928.
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In the present paper, a comprehensive methodology for the thermoeconomic performance optimization of an intercooled reheat (ICRH) gas turbine with recuperation for cogenerative applications has been presented covering a wide range of power-to-heat ratio values achievable. To show relative changes in the thermoeconomic performance for the recuperated ICRH gas turbine cycle, results for ICRH, recuperated Brayton and simple Brayton cycles are also included in the paper. For the three load cases investigated, the recuperated ICRH gas turbine cycle provides the highest values of electric efficiency and Energy Saving Index for the cogenerative systems requiring low thermal loads (high power-to-heat ratio) compared to the other cycles. Also, this study showed, in general, that the recuperated ICRH cycle permits wider power-to-heat ratio range compared to the other cycles and for different load cases examined, a beneficial thermodynamic characteristic for the cogeneration applications. Furthermore, this study clearly shows that implementation of the recuperated ICRH cycle in a cogeneration system will permit to design a gas turbine which has the high specific work capacity and high electric efficiency at low value of the overall cycle pressure ratio compared to the other cycles studied. Economic performance of the investigated gas turbine cycles have been found dependent on the power-to-heat ratio value and the selected cost structure (fuel cost, electric sale price, steam sale price, etc.), the results for a selected cost structure in the study are discussed in this paper.
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Valamin, A. E., A. Yu Kultyshev, A. A. Gol’dberg, et al. "The T-125/150-12.8 cogeneration steam turbine." Thermal Engineering 61, no. 12 (2014): 849–56. http://dx.doi.org/10.1134/s0040601514120076.
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Morozenko, M. I. "Optimal Values of Power Equipment Parameters when Degassing of Solid Municipal Waste Polygons." Ecology and Industry of Russia 28, no. 8 (2024): 4–9. http://dx.doi.org/10.18412/1816-0395-2024-8-4-9.
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The possibility of using the energy values of landfill gas to generate electrical and thermal energy based on a contact cogeneration gas turbine installation has been studied. The optimal values degree of increase pressure in the cycle are determined, which make it possible to determine the maximum specific electrical power and thermodynamic efficiency of a cogeneration gas turbine installation with steam injection, in which landfill gas from solid waste landfills is used as an energy carrier. It is concluded that using the proposed engineering solution, landfill gas from municipal solid waste can be usefully implemented in a cogeneration contact gas turbine installation, which will save the country's national wealth and at the same time solve pressing problems of modern cities associated with the disposal of municipal solid waste.
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O'Brien and, J. M., and P. K. Bansal. "Modelling of cogeneration systems Part 3: Application of steam turbine cogeneration analysis to Auckland Hospital cogeneration utility system." Proceedings of the Institution of Mechanical Engineers, Part A: Journal of Power and Energy 214, no. 3 (2000): 227–41. http://dx.doi.org/10.1243/0957650001538326.
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Steam turbine cogeneration analysis (STuCA) is a quasi-static steam cogneration plant modelling tool, which has been developed and applied to the Auckland Hospital energy centre at Auckland, New Zealand. The STuCA code consists of four submodels, namely a load, a system, a plant and an economic model. The load model was developed using historical data and drove the system model, which consisted of heat exchangers. The system model output was then used to drive the plant model that modelled the turbine and boiler and predicted the primary energy flows and cash flows at the site. Economic analysis tools including thermodynamic, thermoeconomic and economic performance measures such as the payback period and the net present value used these data to analyse the economic performance measures such as the payback period and the net present value used these data to analyse the economic performance of the site. The STuCA model output correlated to site data to within 10 per cent and provided data that could be used by the economic analysis tools. The application of the STuCA model to the hospital site proved that it could be used to design cogeneration plants, to analyse retrofit, to upgrade proposals and to study the effects of changing site loads on plant performance.
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Baughn, J. W., and N. Bagheri. "The Effect of Thermal Matching on the Thermodynamic Performance of Gas Turbine and IC Engine Cogeneration Systems." Journal of Engineering for Gas Turbines and Power 109, no. 1 (1987): 39–45. http://dx.doi.org/10.1115/1.3240004.
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Computer models have been used to analyze the thermodynamic performance of a gas turbine (GT) cogeneration system and an internal combustion engine (IC) cogeneration system. The purpose of this study was to determine the effect of thermal matching of the load (i.e., required thermal energy) and the output steam fraction (fraction of the thermal output, steam and hot water, which is steam) on the thermodynamic performance of typical cogeneration systems at both full and partial output. The thermodynamic parameters considered were: the net heat rate (NHR), the power-to-heat ratio (PHR), and the fuel savings rate (FSR). With direct use (the steam fractions being different), the NHR of these two systems is similar at full output, the NHR of the IC systems is lower at partial output, and the PHR and the FSR of the GT systems are lower than those of the IC systems over the full range of operating conditions. With thermal matching (to produce a given steam fraction) the most favorable NHR, PHR, and FSR depend on the method of matching the load to the thermal output.
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Hristov, Kaloyan. "Study of the efficiency of the joint operation of a cogeneration steam turbine with a heat pump installation." IOP Conference Series: Earth and Environmental Science 1380, no. 1 (2024): 012024. http://dx.doi.org/10.1088/1755-1315/1380/1/012024.
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Abstract In the source of heat energy for centralized heat supply systems, the joint production (cogeneration) of heat and electricity in one energy conversion unit is most often implemented. In most cases, the cogeneration technologies are based on steam turbine installations. Combined heat and power (CHP) generation is undoubtedly a method where the energy of the fuel input for both products is used more efficiently, in contrast to the production of the same amounts of energy by the split production method. To increase the efficiency of cogeneration plants a low potential heat source can be used. For this purpose, in this paper, based on simulation modelling, a comparative analysis of the operation of a combined heat and power steam turbine plant with a heat pump plant with a low-potential heat source will be carried out. In the study, the mains water that is fed for preheating is used as the low-potential heat source.
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Baughn, J. W., and R. A. Kerwin. "A Comparison of the Predicted and Measured Thermodynamic Performance of a Gas Turbine Cogeneration System." Journal of Engineering for Gas Turbines and Power 109, no. 1 (1987): 32–38. http://dx.doi.org/10.1115/1.3240003.
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The thermodynamic performance of a gas turbine cogeneration system is predicted using a computer model. The predicted performance is compared to the actual performance, determined by measurements, in terms of various thermodynamic performance parameters which are defined and discussed in this paper. These parameters include the electric power output, fuel flow rate, steam production, electrical efficiency, steam efficiency, and total plant efficiency. Other derived parameters are the net heat rate, the power-to-heat ratio, and the fuel savings rate. This paper describes the cogeneration plant, the computer model, and the measurement techniques used to determine each of the necessary measurands. The predicted and the measured electric power compare well. The predicted fuel flow and steam production are less than measured. The results demonstrate that this type of comparison is needed if computer models are to be used successfully in the design and selection of cogeneration systems.
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Lampart, Piotr, Łukasz Witanowski, and Piotr Klonowicz. "Efficiency Optimisation of Blade Shape in Steam and ORC Turbines." Mechanics and Mechanical Engineering 22, no. 2 (2020): 553–64. http://dx.doi.org/10.2478/mme-2018-0044.
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AbstractThis paper is devoted to direct constrained optimisation of blading systems of large power and small power turbines so as to increase their internal efficiency. The optimisation is carried out using hybrid stochastic-deterministic methods such as a combination of a direct search method of Hooke-Jeeves and simulated annealing or a combination of a bat algorithm and simplex method of Nelder-Mead. Among free shape parameters are blade number and stagger angle, stacking blade line parameters and blade section (profile) parameters.One practical example of efficiency optimisation of turbine blading systems is modification of low load profiles PLK-R2 for high pressure (HP) stages of large power steam turbines. Another optimised geometry is that of an ORC radial-axial cogeneration turbine of 50 kWe. Up to 1% efficiency increase can easily be obtained from optimisation of HP blade profiles, especially by making the rotor blade more aft-loaded and reducing the intensity of endwall flows. Almost 2% efficiency rise was obtained for the optimised 50 kWe ORC turbine due to flow improvement at the suction side of the blade.
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Velikovich, V. I., Yu M. Brodov, and M. A. Nirenshtein. "Condensers for cogeneration steam-turbine units of the Ural Turbine Works." Thermal Engineering 55, no. 8 (2008): 654–59. http://dx.doi.org/10.1134/s0040601508080041.
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Pietrasanta, Ariana M., Sergio F. Mussati, Pio A. Aguirre, Tatiana Morosuk, and Miguel C. Mussati. "Optimization of Cogeneration Power-Desalination Plants." Energies 15, no. 22 (2022): 8374. http://dx.doi.org/10.3390/en15228374.
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The design of new dual-purpose thermal desalination plants is a combinatory problem because the optimal process configuration strongly depends on the desired targets of electricity and freshwater. This paper proposes a mathematical model for selecting the optimal structure, the operating conditions, and sizes of all system components of dual-purpose thermal desalination plants. Electricity is supposed to be generated by a combined-cycle heat and power plant (CCHPP) with the following candidate structures: (a) one or two gas turbines; (b) one or two additional burners in the heat recovery steam generator; (c) the presence or missing a medium-pressure steam turbine; (d) steam generation and reheating at low pressure. Freshwater is supposed to be obtained from two candidate thermal processes: and (e) a multi-effect distillation (MED) or a multi-stage flash (MSF) system. The number of effects in MED and stages in MSF are also discrete decisions. Different case studies are presented to show the applicability of the model for same cost data. The proposed model is a powerful tool in optimizing new plants (or plants under modernization) and/or improving existing plants for desired electricity generation and freshwater production. No articles addressing the optimization involving the discrete decisions mentioned above are found in the literature.
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Korakianitis, T., J. Grantstrom, P. Wassingbo, and Aristide F. Massardo. "Parametric Performance of Combined-Cogeneration Power Plants With Various Power and Efficiency Enhancements." Journal of Engineering for Gas Turbines and Power 127, no. 1 (2005): 65–72. http://dx.doi.org/10.1115/1.1808427.
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The design-point performance characteristics of a wide variety of combined-cogeneration power plants, with different amounts of supplementary firing (or no supplementary firing), different amounts of steam injection (or no steam injection), different amounts of exhaust gas condensation, etc., without limiting these parameters to present-day limits are investigated. A representative power plant with appropriate components for these plant enhancements is developed. A computer program is used to evaluate the performance of various power plants using standard inputs for component efficiencies, and the design-point performance of these plants is computed. The results are presented as thermal efficiency, specific power, effectiveness, and specific rate of energy in district heating. The performance of the simple-cycle gas turbine dominates the overall plant performance; the plant efficiency and power are mainly determined by turbine inlet temperature and compressor pressure ratio; increasing amounts of steam injection in the gas turbine increases the efficiency and power; increasing amounts of supplementary firing decreases the efficiency but increases the power; with sufficient amounts of supplementary firing and steam injection the exhaust-gas condensate is sufficient to make up for water lost in steam injection; and the steam-turbine power is a fraction (0.1 to 0.5) of the gas-turbine power output. Regions of “optimum” parameters for the power plant based on design-point power, hot-water demand, and efficiency are shown. A method for fuel-cost allocation between electricity and hot water is recommended.
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Barbosa dos Santos, Paulo Sérgio, Ricardo Alan Verdú Ramos, Marcelo Caldato Fiomari, Emanuel Rocha Woiski, and Thaisa Calvo Fugineri Moreti. "Performance analysis of a condensation-extraction steam turbine operating in a sugar-alcohol factory cogeneration system." International Journal for Innovation Education and Research 7, no. 8 (2019): 275–90. http://dx.doi.org/10.31686/ijier.vol7.iss8.1675.
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In this work a thermodynamic analysis for a condensation-extraction steam turbine capable of driving a 40 MVA electric generator in a sugar-alcohol factory was carried out. Sensibility analyses were performed to evaluate the behavior of the overall energy efficiency of a plant with the condensation-extraction steam turbine in function of the boiler efficiency, the specific consumption of steam in the processes as well as the condensation rate in the turbine. The analysis results have shown that this turbine in the cogeneration system contribute to increasing the power generation, although the condensation reduces the overall efficiency of the plant. It has also been observed that the plant efficiency is very sensitive to the condensation rate variation and increases with the demand for steam in the processes.
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Sancho-Bastos, Francisco, and Horacio Perez-Blanco. "Cogeneration System Simulation and Control to Meet Simultaneous Power, Heating, and Cooling Demands." Journal of Engineering for Gas Turbines and Power 127, no. 2 (2005): 404–9. http://dx.doi.org/10.1115/1.1789993.
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Gas turbines are projected to meet increasing power demand throughout the world. Cogeneration plants hold the promise of increased efficiency at acceptable cost. In a general case, a cogen plant could be able to meet power, heating and cooling demands. Yet those demands are normally uncoupled. Control and storage strategies need to be explored to ensure that each independent demand will be met continuously. A dynamic model of a mid-capacity system is developed, including gas and steam turbines, two heat recovery steam generators (HRSG) and an absorption-cooling machine. Controllers are designed using linear quadratic regulators (LQR) to control two turbines and a HRSG with some novelty. It is found that the power required could be generated exclusively with exhaust gases, without a duct burner in the high-pressure HRSG. The strategy calls for fuel and steam flow rate modulation for each turbine. The stability of the controlled system and its performance are studied and simulations for different demand cases are performed.