The Experts below are selected from a list of 12570 Experts worldwide ranked by ideXlab platform
Paulo Smith Schneider - One of the best experts on this subject based on the ideXlab platform.
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reprint of performance analysis of a ccgt power Plant integrated to a lng reGasification process
Journal of Natural Gas Science and Engineering, 2015Co-Authors: Diogo Angelo Stradioto, Marina Fonseca Seelig, Paulo Smith SchneiderAbstract:Abstract This paper examines the performance of a combined cycle Gas Turbine Plant (CCGT) when integrated to the cold energy released during the reGasification process of liquefied natural Gas (LNG). A growing number of LNG import terminals supply reGasified natural Gas for power generation, with an adjacent CCGT Plant providing an anchor market for the facility itself. Two integration alternatives with mutual energetic gains are proposed and simulated, and compared to a reference case without any use of the LNG cold potential. The first alternative consists on exchanging heat among LNG and the Brayton cycle air intake. The second alternative adds to the first one a novel recovery opportunity by exchanging heat with the Rankine cycle condenser. On both cases, heat from the CCGT is rejected to a lower temperature level than the one of the regular dead state. From the reGasification side, the process is performed without any help of extra external energy. Both integration alternatives led to an electrical efficiency enhancement when comparing to the non-integrated cycle: 6.32% and 9.09%, respectively. The energy return on investment (EROI) of each alternative was also analyzed and gains of 12.92% and 18.57% are predicted by upon the simulation data.
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performance analysis of a ccgt power Plant integrated to a lng reGasification process
Journal of Natural Gas Science and Engineering, 2015Co-Authors: Diogo Angelo Stradioto, Marina Fonseca Seelig, Paulo Smith SchneiderAbstract:Abstract This paper examines the performance of a combined cycle Gas Turbine Plant (CCGT) when integrated to the cold energy released during the reGasification process of liquefied natural Gas (LNG). A growing number of LNG import terminals supply reGasified natural Gas for power generation, with an adjacent CCGT Plant providing an anchor market for the facility itself. Two integration alternatives with mutual energetic gains are proposed and simulated, and compared to a reference case without any use of the LNG cold potential. The first alternative consists on exchanging heat among LNG and the Brayton cycle air intake. The second alternative adds to the first one a novel recovery opportunity by exchanging heat with the Rankine cycle condenser. On both cases, heat from the CCGT is rejected to a lower temperature level than the one of the regular dead state. From the reGasification side, the process is performed without any help of extra external energy. Both integration alternatives led to an electrical efficiency enhancement when comparing to the non-integrated cycle: 6.32% and 9.09%, respectively. The energy return on investment (EROI) of each alternative was also analyzed and gains of 12.92% and 18.57% are predicted by upon the simulation data.
Colin F Mcdonald - One of the best experts on this subject based on the ideXlab platform.
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power conversion system considerations for a high efficiency small modular nuclear Gas Turbine combined cycle power Plant concept ngtcc
Applied Thermal Engineering, 2014Co-Authors: Colin F McdonaldAbstract:Abstract The power conversion system (PCS) in the proposed small modular combined cycle nuclear Gas Turbine Plant is based on the coupling of a non-intercooled topping helium Brayton direct closed-cycle Gas Turbine and a single-reheat supercritical steam Rankine bottoming cycle. The nuclear heat source (with a thermal rating of 350 MWt) is a helium cooled and graphite moderated very high temperature reactor (VHTR) embodying an assembly of prismatic fuel elements. Based on a reactor outlet (and Gas Turbine inlet) temperature of 95 °C, the module electrical power output is 180 MWe (50 and 130 MWe from the Gas and steam Turbines respectively) with an estimated Plant efficiency of 51.5 percent. The design and development of the proposed nuclear Gas Turbine combined cycle (NGTCC) concept would benefit from established technology bases. With the inclusion of a process heat extraction module embodying a compact steam-to-steam re-boiler the proposed Plant concept could operate in a cogeneration mode, namely generating electrical power plus providing a supply of uncontaminated process steam to various industrial users. This paper addresses projected HTR to VHTR Plant evolution, thermodynamic cycle selection, Plant performance, tentative arrangement of the combined cycle PCS, component design considerations and their technology bases, and major development requirements. The NGTCC is an advanced long-term helium cooled reactor concept, and a single module demonstration Plant may be realizable by say circa 2030, this leading to commercial operation of multi-module Plants, and paving the way for future very high temperature nuclear process heat Plants in the middle decades of the 21st century.
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helium turbomachinery operating experience from Gas Turbine power Plants and test facilities
Applied Thermal Engineering, 2012Co-Authors: Colin F McdonaldAbstract:Abstract The closed-cycle Gas Turbine, pioneered and deployed in Europe, is not well known in the USA. Since nuclear power Plant studies currently being conducted in several countries involve the coupling of a high temperature Gas-cooled nuclear reactor with a helium closed-cycle Gas Turbine power conversion system, the experience gained from operated helium turbomachinery is the focus of this paper. A study done as early as 1945 foresaw the use of a helium closed-cycle Gas Turbine coupled with a high temperature Gas-cooled nuclear reactor, and some two decades later this was investigated but not implemented because of lack of technology readiness. However, the first practical use of helium as a Gas Turbine working fluid was recognized for cryogenic processes, and the first two small fossil-fired helium Gas Turbines to operate were in the USA for air liquefaction and nitrogen production facilities. In the 1970's a larger helium Gas Turbine Plant and helium test facilities were built and operated in Germany to establish technology bases for a projected future high efficiency large nuclear Gas Turbine power Plant concept. This review paper covers the experience gained, and the lessons learned from the operation of helium Gas Turbine Plants and related test facilities, and puts these into perspective since over three decades have passed since they were deployed. An understanding of the many unexpected events encountered, and how the problems, some of them serious, were resolved is important to avoid them being replicated in future helium turbomachines. The valuable lessons learned in the past, in many cases the hard way, particularly from the operation in Germany of the Oberhausen II 50 MWe helium Gas Turbine Plant, and the technical know-how gained from the formidable HHV helium Turbine test facility, are viewed as being germane in the context of current helium turbomachine design work being done for future high efficiency nuclear Gas Turbine Plant concepts.
Diogo Angelo Stradioto - One of the best experts on this subject based on the ideXlab platform.
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reprint of performance analysis of a ccgt power Plant integrated to a lng reGasification process
Journal of Natural Gas Science and Engineering, 2015Co-Authors: Diogo Angelo Stradioto, Marina Fonseca Seelig, Paulo Smith SchneiderAbstract:Abstract This paper examines the performance of a combined cycle Gas Turbine Plant (CCGT) when integrated to the cold energy released during the reGasification process of liquefied natural Gas (LNG). A growing number of LNG import terminals supply reGasified natural Gas for power generation, with an adjacent CCGT Plant providing an anchor market for the facility itself. Two integration alternatives with mutual energetic gains are proposed and simulated, and compared to a reference case without any use of the LNG cold potential. The first alternative consists on exchanging heat among LNG and the Brayton cycle air intake. The second alternative adds to the first one a novel recovery opportunity by exchanging heat with the Rankine cycle condenser. On both cases, heat from the CCGT is rejected to a lower temperature level than the one of the regular dead state. From the reGasification side, the process is performed without any help of extra external energy. Both integration alternatives led to an electrical efficiency enhancement when comparing to the non-integrated cycle: 6.32% and 9.09%, respectively. The energy return on investment (EROI) of each alternative was also analyzed and gains of 12.92% and 18.57% are predicted by upon the simulation data.
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performance analysis of a ccgt power Plant integrated to a lng reGasification process
Journal of Natural Gas Science and Engineering, 2015Co-Authors: Diogo Angelo Stradioto, Marina Fonseca Seelig, Paulo Smith SchneiderAbstract:Abstract This paper examines the performance of a combined cycle Gas Turbine Plant (CCGT) when integrated to the cold energy released during the reGasification process of liquefied natural Gas (LNG). A growing number of LNG import terminals supply reGasified natural Gas for power generation, with an adjacent CCGT Plant providing an anchor market for the facility itself. Two integration alternatives with mutual energetic gains are proposed and simulated, and compared to a reference case without any use of the LNG cold potential. The first alternative consists on exchanging heat among LNG and the Brayton cycle air intake. The second alternative adds to the first one a novel recovery opportunity by exchanging heat with the Rankine cycle condenser. On both cases, heat from the CCGT is rejected to a lower temperature level than the one of the regular dead state. From the reGasification side, the process is performed without any help of extra external energy. Both integration alternatives led to an electrical efficiency enhancement when comparing to the non-integrated cycle: 6.32% and 9.09%, respectively. The energy return on investment (EROI) of each alternative was also analyzed and gains of 12.92% and 18.57% are predicted by upon the simulation data.
Fredrik Haglind - One of the best experts on this subject based on the ideXlab platform.
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thermodynamic analysis of an integrated Gasification solid oxide fuel cell Plant combined with an organic rankine cycle
Renewable Energy, 2013Co-Authors: Leonardo Pierobon, Ulrik Larsen, Fredrik HaglindAbstract:A 100 kWe hybrid Plant consisting of Gasification system, solid oxide fuel cells and organic Rankine cycle is presented. The nominal power is selected based on cultivation area requirement. For the considered output a land of around 0.5 km2 needs to be utilized. Woodchips are introduced into a fixed bed Gasification Plant to produce synGas which fuels the combined solid oxide fuel cells e organic Rankine cycle system to produce electricity. More than a hundred fluids are considered as possible alternative for the organic cycle using non-ideal equations of state (or state-of-the-art equations of state). A genetic algorithm is employed to select the optimal working fluid and the maximum pressure for the bottoming cycle. Thermodynamic and physical properties, environmental impacts and hazard specifications are also considered in the screening process. The results suggest that efficiencies in the region of 54e56% can be achieved. The highest thermal efficiency (56.4%) is achieved with propylcyclohexane at 15.9 bar. A comparison with the available and future technologies for biomass to electricity conversion is carried out. It is shown that the proposed system presents twice the thermal efficiency achieved by simple and double stage organic Rankine cycle Plants and around the same efficiency of a combined Gasification, solid oxide fuel cells and micro Gas Turbine Plant.
Alok Ku Mohapatra - One of the best experts on this subject based on the ideXlab platform.
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comparative analysis of inlet air cooling techniques integrated to cooled Gas Turbine Plant
Journal of The Energy Institute, 2015Co-Authors: Alok Ku MohapatraAbstract:Abstract The current article is focused on assessing the comparison of two different means of inlet air cooling (evaporative cooing and vapor compression cooling) integrated to a cooled Gas Turbine power Plant. Air film cooling has been adopted as the cooling technique for Gas Turbine buckets. A parametric study of the effect of pressure ratio (r p,c ), compressor inlet temperature (CIT), Turbine inlet temperature (TIT), inlet temperature ratio (r IT ), ambient relative humidity and ambient temperature on performance parameters of Plant has been carried out. It has been observed that the integration of the inlet air cooling system to the Gas Turbine cycle improves the overall performance, the improvement being higher at higher ambient temperature and ambient relative humidity. At a TIT = 1700 K, r p,c = 23, RH a = 0.2 and T a = 313 K, vapor compression inlet air cooling has been observed to improve the Plant specific work by 18.4% and efficiency by 4.18%, compared to 10.48% and 4.6% respectively for evaporative cooling. In geographical regions having low ambient relative humidity and low ambient temperature however, evaporative inlet air cooling should be preferred over vapor compression cooling in terms of higher Plant efficiency.. The adoption of higher Turbine inlet temperature has a more pronounced effect on vapor compression cooled Gas Turbine in terms of enhancement in Plant performance parameters as compared to evaporative cooling. The work ratio increases with increase in value of r IT upto5.6 after which it decreases.