Relevant bibliographies by topics / Gas power plants

Contents

  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers
  6. Reports

Academic literature on the topic 'Gas power plants'

Author: Grafiati
Published: 4 June 2021
Last updated: 31 July 2024

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Journal articles on the topic "Gas power plants"

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Goossens, M. A. "Landfill gas power plants." Renewable Energy 9, no. 1-4 (September 1996): 1015–18. http://dx.doi.org/10.1016/0960-1481(96)88452-7.

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Moore, Keith, and Melbourne F. Giberson. "Reengineered Coal-Fired Power Plants Competitive With Gas Turbine Plants." Natural Gas & Electricity 34, no. 5 (November 15, 2017): 11–16. http://dx.doi.org/10.1002/gas.22021.

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Langston, Lee S. "Gas Turbines - Major Greenhouse Gas Inhibitors." Mechanical Engineering 137, no. 12 (December 1, 2015): 54–55. http://dx.doi.org/10.1115/1.2015-nov-5.

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This article explains how combined cycle gas turbine (CCGT) power plants can help in reducing greenhouse gas from the atmosphere. In the last 25 years, the development and deployment of CCGT power plants represent a technology breakthrough in efficient energy conversion, and in the reduction of greenhouse gas production. Existing gas turbine CCGT technology can provide a reliable, on-demand electrical power at a reasonable cost along with a minimum of greenhouse gas production. Natural gas, composed mostly of methane, is a hydrocarbon fuel used by CCGT power plants. Methane has the highest heating value per unit mass of any of the hydrocarbon fuels. It is the most environmentally benign of fuels, with impurities such as sulfur removed before it enters the pipeline. If a significant portion of coal-fired Rankine cycle plants are replaced by the latest natural gas-fired CCGT power plants, anthropogenic carbon dioxide released into the earth’s atmosphere would be greatly reduced.
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Kobernik, V. S. "Fuel consumption of thermal power technologies under maneuvering modes." Problems of General Energy 2020, no. 4 (December 22, 2020): 45–49. http://dx.doi.org/10.15407/pge2020.04.045.

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A characteristic feature of the present day development of power engineering lies in the increase in the unevenness of power systems schedules. The structure of generating powers of Ukrainian energy engineering is overloaded with basic powers and characterized by a sharp deficit of maneuvering wanes. To cover the uneven load of the power system during the operation of existing and construction of new power plants, it is necessary to take into account the possibility of their operation under maneuvering modes. This paper determines the influence of work of power plants i under maneuvering modes on the specific consumption of conditional fuel on the released electric energy at working on gas or coal fuel. Fuel consumption for starting of a unit depends on its type and downtime in reserve. The use of steam–and–gas facilities and gas turbines helps to enhance the maneuverability of power plants. Alternative options for the development of thermal energy are the introduction of gas–piston power plants and power units with fluidized–bed boilers. We present formulas for the calculations of fuel consumption on by power units for start–ups and specific consumptions depending on the load and degree of their involvement to regulating loads for different thermal energy technologies: steam–turbine condensation and district heating power units; steam–and–gas and gas turbine plants; gas piston installations; power units with fluidized bed boilers. For enhancing the maneuverability of power plants, working on fossil fuels, their modernization and renewal of software are necessary. Quantitative assessment of the efficiency of power units and separate power plants during their operation under variable modes is important for forecasting the structure of generating capacities of power systems, the need to introduce peak and semi–peak capacities, the choice of the most profitable composition of operating equipment at different schedules of electrical loads Keywords: thermal power, power unit, maneuverable mode, electrical load, specific fuel consumption
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Rogalev, N. D. "CARBON FOOTPRINT COMPARATIVE ANALYSIS FOR EXISTING AND PROMISING THERMAL POWER PLANTS." Eurasian Physical Technical Journal 19, no. 4 (December 26, 2022): 34–43. http://dx.doi.org/10.31489/2022no4/34-43.

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The power production industry is the main greenhouse gas emitter that makes its contribution to global warming. The greenhouse gas emission takes place in fuel production, transportation, and combustion. A prospective method for emission mitigation is the transition to organic fuel-burning facilities with small emissions by capturing carbon dioxide. Power consumption on the carbon dioxide capture remarkably reduces the efficiency of these facilities, which leads to increasing of fuel consumption and greenhouse gas emission because of the larger fuel production and transportation. Based on the material balance method, taking into account system effect of changes in efficiency and amount of fuel consumed, the paper estimated the carbon footprint over a twenty-year lifecycle for following thermal power plants types: combined cycle and oxy-fuel combustion plants for both natural gas and coal with internal gasification. It is shown that the transition to oxygen-fuel plants can reduce the carbon footprint near 90% for natural gas and near 75% for coal. The study also demonstrates the positive effect of carbon capture and storage system implementation for reducing carbon footprint near 75% for natural gas and near 70% for coal.
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Penner, S. S. "Combined power plants, including Combined Cycle Gas Turbine (CCGT) plants." Energy 18, no. 6 (June 1993): 703. http://dx.doi.org/10.1016/0360-5442(93)90049-j.

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Ulloa, Carlos, Guillermo Rey, Ángel Sánchez, and Ángeles Cancela. "Power Plants, Steam and Gas Turbines WebQuest." Education Sciences 2, no. 4 (October 24, 2012): 180–89. http://dx.doi.org/10.3390/educsci2040180.

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Rochman, C., D. Nasrudin, A. R. Juwita, and N. Fitriyanti. "Student physics literacy on gas power plants." Journal of Physics: Conference Series 1918, no. 5 (June 1, 2021): 052063. http://dx.doi.org/10.1088/1742-6596/1918/5/052063.

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Saturday, Ebigenibo Genuine, and Tamunobelema Justice Okumgba. "Performance Assessment of Gas Turbine Power Plants." Saudi Journal of Engineering and Technology 5, no. 6 (June 18, 2020): 265–70. http://dx.doi.org/10.36348/sjet.2020.v05i06.002.

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Doichinova, Maria, Petya Popova-Krumova, Christo Boyadjiev, and Boyan Boyadjiev. "Gas Purification from SO2in Thermal Power Plants." Chemical Engineering & Technology 37, no. 7 (June 25, 2014): 1243–50. http://dx.doi.org/10.1002/ceat.201300612.

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Dissertations / Theses on the topic "Gas power plants"

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Austrem, Inger. "The exergy efficiency of hydrogen-fired gas power plants." Thesis, Norwegian University of Science and Technology, Industrial Ecology Programme, 2003. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-1427.

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The work includes an exergy analysis of the steam reforming process for conversion of natural gas to hydrogen rich gas for use in hydrogen-fired gas power plant. Based on the analysis two sustainability indicators were calculated, the exergetic efficiency and the renewability fraction. The same analysis has been performed for a system using auto thermal reformer (Zvolinschi, Kjelstrup, Bolland and van der Kooi 2002) instead of steam reformer, and the results were compared in order to find the better system of the two based on the indicators. The system using an auto thermal reformer had the best exergetic efficiency, and the renewability fraction was 0 for both systems. One should be aware of insecurities in the results, mainly related to assumptions and limitations with respect to the simulation process.

The two indicators were proposed by Zvolinschi et. al, as a contribution to the introduction of exergy analysis as a tool for industrial ecology. It was concluded that this will be a useful contribution, especially when using system boundaries that include the closure of material cycles. Then one can also calculate the third indicator proposed by Zvolinschi et al., namely the environmental efficiency.

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Spelling, James. "Hybrid Solar Gas-Turbine Power Plants : A Thermoeconomic Analysis." Doctoral thesis, KTH, Kraft- och värmeteknologi, 2013. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-121315.

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The provision of a sustainable energy supply is one of the most importantissues facing humanity at the current time, and solar thermal power hasestablished itself as one of the more viable sources of renewable energy. Thedispatchable nature of this technology makes it ideally suited to forming thebackbone of a future low-carbon electricity system.However, the cost of electricity from contemporary solar thermal power plantsremains high, despite several decades of development, and a step-change intechnology is needed to drive down costs. Solar gas-turbine power plants are apromising new alternative, allowing increased conversion efficiencies and asignificant reduction in water consumption. Hybrid operation is a furtherattractive feature of solar gas-turbine technology, facilitating control andensuring the power plant is available to meet demand whenever it occurs.Construction of the first generation of commercial hybrid solar gas-turbinepower plants is complicated by the lack of an established, standardised, powerplant configuration, which presents the designer with a large number ofchoices. To assist decision making, thermoeconomic studies have beenperformed on a variety of different power plant configurations, includingsimple- and combined-cycles as well as the addition of thermal energy storage.Multi-objective optimisation has been used to identify Pareto-optimal designsand highlight trade-offs between costs and emissions.Analysis of the simple-cycle hybrid solar gas-turbines revealed that, whileelectricity costs were kept low, the achievable reduction in carbon dioxideemissions is relatively small. Furthermore, an inherent trade-off between thedesign of high efficiency and high solar share hybrid power plants wasidentified. Even with the use of new optimised designs, the degree of solarintegration into the gas-turbine did not exceed 63% on an annual basis.In order to overcome the limitations of the simple-cycle power plants, twoimprovements were suggested: the integration of thermal energy storage, andthe use of combined-cycle configurations. Thermal energy storage allowed thedegree of solar operation to be extended, significantly decreasing carbondioxide emissions, and the addition of a bottoming-cycle reduced the electricitycosts. A combination of these two improvements provided the bestperformance, allowing a reduction in carbon dioxide emissions of up to 34%and a reduction in electricity costs of up to 22% compared to a combination ofconventional power generation technologies.
Hållbar energiförsörjning är för närvarande en av de viktigaste frågorna förmänskligheten. Koncentrerad solenergi är nu etablerad som en tillförlitlig källaav förnybar energi. Den reglerbara karaktären hos tekniken gör den specielltintressant för uppbyggnaden av ett framtida koldioxidsnålt elsystem.Kostnaden för elektricitet från nuvarande termiska solkraftverk är hög trottsflera decennier av utveckling. Ett genombrått på tekniknivå krävs för att drivaned kostnaderna. Sol-gasturbiner är ett av de mest lovande alternativen, somger en ökad verkningsgrad samtidigt som vattenkonsumtionen reducerasdrastiskt. Sol-gasturbintekniken gör det möjligt att blandköra solenergi ochandra bränslen för att möta efterfrågan vid alla tidpunkter, en attraktiv aspekt iförhållande till alternativa lösningar.Uppbyggnaden av första generationens kommersiella hybrida solgasturbinkraftverkförsvåras dock av bristen på etablerade och standardiseradekraftverkskonfigurationer. Dessa ger planeraren ett stort antal valmöjlighetersom underlag för beslutsfattande. Termoekonomiska studier har genomförtsför ett flertal olika kraftverkskonfigurationer, däribland kraftverk med enkelcykel, kombikraftverk samt möjligheten att utnyttja termisk energilagring.Pareto-optimala konfigurationer har identifierats med hjälp av multiobjektsoptimeringför att belysa balansen mellan kostnader och utsläpp.Analysen av det enkla hybrida sol-gasturbinkraftverket visade attelektricitetskostnaden hållits på en låg nivå, men att den möjliga minskningen avkoldioxidutsläpp är relativt liten. Dessutom identifierades en inre balans mellanatt bibehålla en hög verkningsgrad hos konfigurationen och en hög andelsolenergi i produktionen. Andelen av solenergi i gasturbinen överskred aldrig63% på årlig bas, även med optimerade kraftverkskonfigurationer.Två förbättringar föreslås för att övervinna begränsningarna hos kraftverk medenkel cykel: integration av termisk energilagring samt nyttjande avkombikraftverkskonfigurationer. Termisk energilagring tillåter en ökad andelsolenergi i driften och reducerar koldioxidutsläppen drastiskt, medan denytterligare cykeln hos kombikraftverket reducerar elektricitetskostnaden.Kombinationen av dessa förbättringar ger den bästa prestandan, med enreduktion av koldioxidutsläppen på upp till 34% och reducerade elektricitetskostnaderpå upp till 22% i jämförelse med andra kombinationer avkonventionella kraftverkskonfigurationer.

QC 20130503

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Hu, Yukun. "CO2 capture from oxy-fuel combustion power plants." Licentiate thesis, KTH, Energiprocesser, 2011. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-48666.

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To mitigate the global greenhouse gases (GHGs) emissions, carbon dioxide (CO2) capture and storage (CCS) has the potential to play a significant role for reaching mitigation target. Oxy-fuel combustion is a promising technology for CO2 capture in power plants. Advantages compared to CCS with the conventional combustion technology are: high combustion efficiency, flue gas volume reduction, low fuel consumption, near zero CO2 emission, and less nitrogen oxides (NOx) formation can be reached simultaneously by using the oxy-fuel combustion technology. However, knowledge gaps relating to large scale coal based and natural gas based power plants with CO2 capture still exist, such as combustors and boilers operating at higher temperatures and design of CO2 turbines and compressors. To apply the oxy-fuel combustion technology on power plants, much work is focused on the fundamental and feasibility study regarding combustion characterization, process and system analysis, and economic evaluation etc. Further studies from system perspective point of view are highlighted, such as the impact of operating conditions on system performance and on advanced cycle integrated with oxy-fuel combustion for CO2 capture. In this thesis, the characterization for flue gas recycle (FGR) was theoretically derived based on mass balance of combustion reactions, and system modeling was conducted by using a process simulator, Aspen Plus. Important parameters such as FGR rate and ratio, flue gas composition, and electrical efficiency etc. were analyzed and discussed based on different operational conditions. An advanced evaporative gas turbine (EvGT) cycle with oxy-fuel combustion for CO2 capture was also studied. Based on economic indicators such as specific investment cost (SIC), cost of electricity (COE), and cost of CO2avoidance (COA), economic performance was evaluated and compared among various system configurations. The system configurations include an EvGT cycle power plant without CO2 capture, an EvGT cycle power plant with chemical absorption for CO2 capture, and a combined cycle power plant. The study shows that FGR ratio is of importance, which has impact not only on heat transfer but also on mass transfer in the oxy-coal combustion process. Significant reduction in the amount of flue gas can be achieved due to the flue gas recycling, particularly for the system with more prior upstream recycle options. Although the recycle options have almost no effect on FGR ratio, flue gas flow rate, and system electrical efficiency, FGR options have significant effects on flue gas compositions, especially the concentrations of CO2 and H2O, and heat exchanger duties. In addition, oxygen purity and water/gas ratio, respectively, have an optimum value for an EvGT cycle power plant with oxy-fuel combustion. Oxygen purity of 97 mol% and water/gas ratio of 0.133 can be considered as the optimum values for the studied system. For optional operating conditions of flue gas recycling, the exhaust gas recycled after condensing (dry recycle) results in about 5 percentage points higher electrical efficiency and about 45 % more cooling water consumption comparing with the exhaust gas recycled before condensing (wet recycle). The direct costs of EvGT cycle with oxy-fuel combustion are a little higher than the direct costs of EvGT cycle with chemical absorption. However, as plant size is larger than 60 MW, even though the EvGT cycle with oxy-fuel combustion has a higher COE than the EvGT cycle with chemical absorption, the EvGT cycle with oxy-fuel combustion has a lower COA. Further, compared with others studies of natural gas combined cycle (NGCC), the EvGT system has a lower COE and COA than the NGCC system no matter which CO2 capture technology is integrated.
QC 20111123
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Al-Hamdan, Qusai Zuhair Mohammed. "Design criteria and performance of gas turbines in a combined power and power (CPP) plant for electrical power generation." Thesis, University of Hertfordshire, 2002. http://hdl.handle.net/2299/14041.

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The simple gas turbine engine Operates on the basic Joule-Brayton cycle and it is notorious for its poor thermal efficiency. Several modifications have been made to the simple cycle in order to increase its thermal efficiency but, within the thermal and mechanical stress constrains, the efficiency still ranges between 28 and 35%. However, higher values of energy utilisation efficiency have been claimed in recent years by using low grade heat from the engine exhaust either for district heating or for raising low pressure steam for chemical processes. Both applications are not very attractive in hot countries. The concept of using the low grade thermal energy from the gas turbine exhaust to raise steam in order to drive a steam turbine and generate additional electricity, i. e. the combined power and power or CPP plant would be more attractive in hot countries than the CHP plant. It was hypothesized that the operational parameters, hence the performance of the CPP plant, would depend on the allowable gas turbine entry temperature. Hence, the exhaust gas temperature could not be decided arbitrarily. This thesis deals with the performance of the gas turbine engine operating as a part of the combined power and power plant. In a CPP plant, the gas turbine does not only produce power but also the thermal energy that is required to operate the steam turbine plant at achievable thermal efficiency. The combined gas turbine-steam turbine cycles are thermodynamically analysed. A parametric study for different configurations of the combined gas-steam cycles has been carried out to show the influence of the main parameters on the CPP cycle performance. The parametric study was carried out using realistic values in view of the known constraints and taking into account any feasible future developments. The results of the parametric study show that the maximum CPP cycle efficiency would be at a point for which the gas turbine cycle would have neither its maximum efficiency nor its maximum specific work output. It has been shown that supplementary heating or gas turbine reheating would decrease the CPP cycle efficiency; hence, it could only be justified at low gas turbine inlet temperatures. Also it has been shown that although gas turbine intercooling would enhance the performance of the gas turbine cycle, it would have only a slight effect on the CPP cycle performance. A graphical method for studying operational compatibility, i.e. matching, between gas turbine components has been developed for a steady state or equilibrium operation. The author would like to submit that the graphical method offers a novel and easy to understand approach to the complex problem of component matching. It has been shown that matching conditions between the compressor and the turbine could be satisfied by superimposing the turbine performance characteristics on the compressor performance characteristics providing the axes of both were normalised. This technique can serve as a valuable tool to determine the operating range and the engine running line. Furthermore, it would decide whether the gas turbine engine was operating in a region of adequate compressor and turbine efficiencies. A computer program capable of simulating the steady state off-design conditions of the gas turbine engine as part of the CPP plant has been developed. The program was written in Visual Basic. Also, another program was developed to simulate the steady state off-design operation of the steam turbine power plant. A combination of both programs was used to simulate the combined power plant. Finally, it could be claimed that the computer simulation of the CPP plant makes significant contribution to the design of thermal power plants as it would help in investigating the effects of the performance characteristics of the components on the performance of complete engines at the design and off-design conditions. This investigation of the CPP plant performance can be carried out at the design and engineering stages and thus help to reduce the cost of manufacturing and testing the expensive prototype engines.
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Bashadi, Sarah (Sarah Omer). "Using auxiliary gas power for CCS energy needs in retrofitted coal power plants." Thesis, Massachusetts Institute of Technology, 2010. http://hdl.handle.net/1721.1/59667.

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Thesis (S.M. in Technology and Policy)--Massachusetts Institute of Technology, Engineering Systems Division, Technology and Policy Program, 2010.
Cataloged from PDF version of thesis.
Includes bibliographical references (p. 93-96).
Post-combustion capture retrofits are expected to a near-term option for mitigating CO 2 emissions from existing coal-fired power plants. Much of the literature proposes using power from the existing coal plant and thermal integration of its supercritical steam cycle with the stripper reboiler to supply the energy needed for solvent regeneration and CO2 compression. This study finds that using an auxiliary natural gas turbine plant to meet the energetic demands of carbon capture and compression may make retrofits more attractive compared to using thermal integration in some circumstances. Natural gas auxiliary plants increase the power output of the base plant and reduce technological risk associated with CCS, but require favorable natural gas prices and regional electricity demand for excess electricity to make using an auxiliary plant more desirable. Three different auxiliary plant technologies were compared to integration for 90% capture from an existing, 500 MW supercritical coal plant. CO2 capture and compression is simulated using Aspen Plus and a monoethylamine (MEA) absorption process. Thermoflow software is used to simulate three gas plant technologies. The three technologies assessed are the gas turbine (GT) with heat recovery steam generator (HRSG), gas turbine with HRSG and back pressure steam turbine, and natural gas boiler with back pressure steam turbine. The capital cost of the MEA unit is estimated using the Aspen Icarus Process Evaluator, and the capital cost of the external GT plants are estimated using the Thermoflow Plant Engineering and Cost Estimator. The gas turbine options are found to lead to electricity costs similar to integration, but their performance is highly sensitive to the price of natural gas and the economic impact of integration. Using a GT with a HRSG only has a lower capital cost but generates less excess electricity than the GT with HRSG and back pressure steam turbine. In order to generate enough steam for the reboiler, a significant amount of excess power was produced using both gas turbine configurations. This excess power could be attractive for coal plants located in regions with increasing electricity demand. An alternate capture plant scenario where a greater demand for power exists relative to steam is also considered. The economics of using auxiliary plant power improve slightly under this alternate energy profile scenario, but the most important factors affecting desirability of the auxiliary plant retrofit remain the cost of natural gas, the full cost of integration, and the potential for sale of excess electricity.
by Sarah Bashadi.
S.M.in Technology and Policy
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Russ, Matthias. "Elaboration of Thermo-Economic Models of Solar Gas-Turbine Power Plants." Thesis, KTH, Energiteknik, 2011. http://urn.kb.se/resolve?urn=urn:nbn:se:kth:diva-72483.

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Tsoudis, Evangelos. "Technoeconomic Environmental and Risk Analysis of Marine Gas Turbine Power Plants." Thesis, Cranfield University, 2008. http://hdl.handle.net/1826/3535.

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A novel generic Technoeconomic, Environmental and Risk Analysis (TERA) computational method was developed for marine power plants that are composed of existing or at preliminary design stage marine gas turbines. The method is composed of several numerical models in order to realistically approach the life cycle operation of a marine gas turbine power plant-according to the operational profile of the platform marine vessel type-coupled to an integrated full electric propulsion system and stochastically estimate the power plant’s life cycle net present cost. The development of the TERA method led to the creation of an integrated computational marine vessel operation environment which was given the name “Poseidon”. The performance and exhaust emissions (nitric oxide, carbon monoxide, carbon dioxide and unburned hydrocarbon) of five 25 Megawatt marine gas turbines of the same technology level and design-point overhaul interval were simulated and modelled in “Poseidon”. The exhaust emissions of the modelled gas turbines were calibrated for two combustor technologies: conventional and dry-low emissions for both distillate fuel and natural gas used as fuel. The marine gas turbines are: existing simple cycle, novel twin-mode intercooled cycle, fictional intercooled cycle, fictional recuperated cycle and partly based on an existing design, intercooled/recuperated cycle. Three marine vessel types that require the same power plant output power and configuration but they utilise different operational profiles were also realistically modelled. The marine vessels are: Destroyer, RoPax fast ferry and LNG carrier. It was assumed that the Destroyer’s and RoPax fast ferry’s power plants use distillates fuel and the LNG carrier’s power plant uses compressed natural gas as fuel. Three case studies defined by each of the marine vessels were performed in order to investigate the economic feasibility of the advanced cycle gas turbine power plants in comparison with the power plant composed by existing gas turbines, in a possible future scenario were all four modelled exhaust emission quantities are accurately measured and taxed. The investment on dry-low emissions combustor technology was also investigated as part of each case study. Both technical and economic input datasets are realistic. Due to time restrains the LNG carrier case study features only the intercooled/recuperated gas turbine power plant. Obtained results are presented and discussed separately for each case study.
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Kaldahl, Jonas Aase, and Kristoffer Ingebrigtsen. "Sequential investment in gas fired power plants : A real options analysis." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for industriell økonomi og teknologiledelse, 2014. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-25908.

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This paper presents an empirical analysis of the real options to postpone and cancel sequential investments with time-to-build. Utilizing generator level data that to the best of our knowledge is unique in scope and detail, we look at investments in gas fired combustion and combined cycle generators. We find strong evidence of real option effects. Regulatory uncertainty and profit uncertainty increases the probability of companies postponing and canceling investments. Firms postponing during times of uncertainty is as expected from theory; firms canceling under these conditions is somewhat more surprising.
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Yeung, Hon-chung. "Clean technology advancement in the power industry /." Hong Kong : University of Hong Kong, 1997. http://sunzi.lib.hku.hk/hkuto/record.jsp?B18734765.

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Berry, David A. "Investigation of hot gas desulfurization utilizing a transport reactor." Morgantown, W. Va. : [West Virginia University Libraries], 1999. http://etd.wvu.edu/templates/showETD.cfm?recnum=500.

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Thesis (M.S.)--West Virginia University, 1999.
Title from document title page. Document formatted into pages; contains vi, 101 p. : ill. (some col.) Includes abstract. Includes bibliographical references (p. 82-85).
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Books on the topic "Gas power plants"

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Kehlhofer, Rolf. Combined-cycle gas & steam turbine power plants. Lilburn, GA: Fairmont Press, 1991.

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1951-, Kehlhofer Rolf, ed. Combined-cycle gas & steam turbine power plants. 3rd ed. Tulsa, Okla: Penwell, 2008.

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1951-, Kehlhofer Rolf, and Kehlhofer Rolf 1951-, eds. Combined-cycle gas & steam turbine power plants. 2nd ed. Tusla, Okla: PennWell, 1999.

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Inc, Energy Consulting. Gas-fired cogeneration plant in Stettler. Calgary, Alta: Energy Resources Conservation Board, 1993.

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Commission, California Energy. Comparative analysis of future gas and electric infrastructure options in the California/Mexico border region: Consultant report. [Sacramento, Calif.]: California Energy Commission, 2008.

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Corfee, Karin. Current status, plans, and constraints related to expansion of natural gas-fired power plants, pipelines and bulk electric transmission in the California/Mexico border region. Sacramento, Calif.]: California Energy Commission, 2008.

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Läuferts, Monika. The Johannesburg Gas Works. Johannesburg: Fourthwall Books, 2015.

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James, Newcomb, and Cambridge Energy Research Associates, eds. Generation gap: U.S. natural gas and electric power in the 1990s. Cambridge, MA (Charles Square, 20 University Rd., Cambridge 02138): Cambridge Energy Research Associates, 1991.

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Sangyōshō, Japan Keizai, ed. Feasibility study report CNG power generation project at Bali, Indonesia. [Tokyo]: Ministry of Economy, Trade and Industry, 2006.

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K, Sudarshan, Kaushish S. P, Bakshi A. S, and India. Central Board of Irrigation and Power., eds. Compendium of gas based generating stations in India. New Delhi: Central Board of Irrigation and Power, 2002.

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Book chapters on the topic "Gas power plants"

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Ibrahim, Jimoh, Christoph Loch, and Kishore Sengupta. "Two Power Plants." In How Megaprojects Are Damaging Nigeria and How to Fix It, 151–60. Cham: Springer International Publishing, 2022. http://dx.doi.org/10.1007/978-3-030-96474-0_8.

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AbstractThis first project, the Egbin Power Plant, was initiated under a civilian government and delayed because of two coups. But then the military government supported the project (which had a strong value proposition) and saw it through.The second project, the Calabar Power Plant, was a part of a large highly ambitious scheme to build 11 power plants, which ran out of money as well as neglecting critical components of the network surrounding a plant (gas supplies and power distribution lines). So, the power plant hardware itself was completed after a delay, but the plant still delivers little power because gas supplies are too expensive and power delivery is subject to capacity limits and price controls that make operation of the plant unaffordable.
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Yang, Zongming, Huabing Wen, Xinglin Yang, Viktor Gorbov, Vira Mitienkova, and Serhiy Serbin. "Marine Gas Turbine Power Plants." In Marine Power Plant, 249–322. Singapore: Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-33-4935-3_6.

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Kanoglu, Mehmet, and Ali Bolatturk. "Thermodynamic Analysis of Geothermal Power Plants." In Alternative Energy and Shale Gas Encyclopedia, 290–300. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2016. http://dx.doi.org/10.1002/9781119066354.ch28.

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Wehowsky, P., D. Stahl, J. de Marcos, and L. Crespo. "The Gas-Cooled Solar Tower Project ‘Gast’." In Thermo-Mechanical Solar Power Plants, 433–38. Dordrecht: Springer Netherlands, 1985. http://dx.doi.org/10.1007/978-94-009-5402-1_64.

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Guan, Zhiqiang, Kamel Hooman, and Hal Gurgenci. "Dry Cooling Towers for Geothermal Power Plants." In Alternative Energy and Shale Gas Encyclopedia, 333–49. Hoboken, NJ, USA: John Wiley & Sons, Inc., 2016. http://dx.doi.org/10.1002/9781119066354.ch32.

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Yang, Xinglin, Zongming Yang, Huabing Wen, Viktor Gorbov, Vira Mitienkova, and Serhiy Serbin. "Liquefied Natural Gas as Marine Fuel." In Alternative Fuels in Ship Power Plants, 83–110. Singapore: Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-33-4850-9_3.

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Syam, Dhruba J. "Gas Turbine Driven Thermal Power Plants (GTG Plants) Combined Cycle Power Plants (CCPP) Diesel Generating Sets (DG Sets)." In Electrical Power Generation, 49–64. London: CRC Press, 2023. http://dx.doi.org/10.1201/9781003403128-4.

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El Hefni, Baligh, and Daniel Bouskela. "Gas Turbine Modeling." In Modeling and Simulation of Thermal Power Plants with ThermoSysPro, 297–309. Cham: Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-05105-1_11.

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Sisti, G., and G. Ferrari Aggradi. "Expert Diagnostic System for Gas Turbines." In Diagnostics of Rotating Machines in Power Plants, 99–109. Vienna: Springer Vienna, 1994. http://dx.doi.org/10.1007/978-3-7091-2706-3_7.

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Zohuri, Bahman, and Patrick McDaniel. "Open Air-Brayton Gas Power Cycle." In Combined Cycle Driven Efficiency for Next Generation Nuclear Power Plants, 175–97. Cham: Springer International Publishing, 2017. http://dx.doi.org/10.1007/978-3-319-70551-4_8.

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Conference papers on the topic "Gas power plants"

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Ghezel-Ayagh, Hossein, Joseph M. Daly, and Zhao-Hui Wang. "Advances in Direct Fuel Cell/Gas Turbine Power Plants." In ASME Turbo Expo 2003, collocated with the 2003 International Joint Power Generation Conference. ASMEDC, 2003. http://dx.doi.org/10.1115/gt2003-38941.

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This paper summarizes the recent progress in the development of hybrid power systems based on Direct FuelCell/Turbine® (DFC/T®). The DFC/T system is capable of achieving efficiencies well in excess of state-of-the-art gas turbine combined cycle power plants but in much smaller size plants. The advances include the execution of proof-of-concept tests of a fuel cell stack integrated with a microturbine. The DFC/T design concept has also been extended to include the existing gas turbine technologies as well as more advanced ones. This paper presents the results of successful sub-MW proof-of-concept testing, sub-MW field demonstration plans, and parametric analysis of multi-MW DFC/T power plant cycle.
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Mita, T., H. Ohara, S. Hoizumi, and N. Ando. "Construction of Combined Cycle Power Generation Plants for Kawagoe Power Station by Chubu Electric Power." In ASME 1994 International Gas Turbine and Aeroengine Congress and Exposition. American Society of Mechanical Engineers, 1994. http://dx.doi.org/10.1115/94-gt-492.

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In response to the recent rapid increase in power demand, Chubu Electric Power is now constructing two 1,650-megawatt power plants, each consisting of seven single-shaft combined-cycle units. These will be plant Nos. 3 and 4 of the Kawagoe Power Station. As one unit of plants, these power plants not only will be among the most powerful (in output) in the world, but will also offer the following features: 1) The main equipment of these plants, a gas turbine, will be a GE-Hitachi Model F7FA, the state-of-the-art 60 Hz model, for large equipment capacity and high efficiency. The heat recovery steam generator of each plant will use serrated fin tubes for high efficiency and compactness. 2) Plant efficiency will be at least 48.5% by means of optimizing the combined-cycle system and using the single-shaft triple-pressure reheat cycle. 3) As middle-load thermal plants, these plants are designed to use the advantages of a single-shaft combined cycle, thus offering operational convenience. 4) For global environmental preservation, which is nowadays an important concern of the local community, these plants are designed to reduce NOx emissions, warm discharge water, and noise. 5) To save labor for operation, and to improve its man-machine interface, these plant will utilize a large screen and CRT operation. Selection of these units and systems has entailed various feasibility studies and simulations for optimization, as well as new developments and reliability verifications. This paper takes the example of plant No. 3 to describe how the method of system selection and to present the design outline.
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Gambini, Marco, and Michela Vellini. "Natural Gas Decarbonisation Technologies for Advanced Power Plants." In ASME 2006 Power Conference. ASMEDC, 2006. http://dx.doi.org/10.1115/power2006-88105.

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In this paper two options for H2 production, by means of natural gas, are presented and their performances are evaluated when they are integrated with advanced H2/air cycles. In this investigation two different schemes have been analysed: an advanced combined cycle power plant (CC) and a new advanced mixed cycle power plant (AMC). The two methods for producing H2 are as follows: • steam methane reforming: it is the simplest and potentially the most economic method for producing hydrogen in the foreseeable future; • partial oxidation of methane: it could offer an energy advantage because this method reduces energy requirement of the reforming process. These hydrogen production plants require material and energetic integrations with power section and the best interconnections must be investigated in order to obtain good overall performance. With reference to thermodynamic and economic performance, significant comparisons have been made between the above introduced reference plants. An efficiency decrease and an increase in the cost of electricity has been obtained when power plants are equipped with a natural gas decarbonisation section. The main results of the performed investigation are quite variable among the different H2 production technologies here considered: the efficiency decreases in a range of 5.5 percentage points to nearly 10 for the partial oxidation of the natural gas and in a range of 8.8 percentage points to over 12 for the steam methane reforming. The electricity production cost increases in a range of about 41–42% for the first option and in a range of about 34–38% for the second one. The AMC, coupled with partial oxidation, stands out among the other power plant solutions here analysed because it exhibits the highest net efficiency and the lowest final specific CO2 emission. In addition to this, economic impact is favourable when AMC is equipped with systems for H2 production based on partial oxidation of natural gas.
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Lugand, Paul, and Yves Boissenin. "VEGA Combined Cycle Power Plants." In ASME 1985 Beijing International Gas Turbine Symposium and Exposition. American Society of Mechanical Engineers, 1985. http://dx.doi.org/10.1115/85-igt-6.

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A gas turbine is often associated with the steam cycle in the combined cycle electric power plants. Many plants of different combined cycle types are already in service, all distinguished by outstanding efficiency (45 to 47 %) and operating flexibility. We have thought it interesting to take stock of the steam and gas (VEGA) cycles especially destined for power plants. After outlining the thermodynamical optimization of the cycles, we shall develop the design and the practical realization of the combined cycle power plants.
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Incer-Valverde, Jimena, Oyeniyi Olaniyi, Tatiana Morosuk, and George Tsatsaronis. "Evaluation of “Natural Gas/Hydrogen” Mixtures for Power to Gas Application." In ASME 2021 International Mechanical Engineering Congress and Exposition. American Society of Mechanical Engineers, 2021. http://dx.doi.org/10.1115/imece2021-71418.

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Abstract Utilization of hydrogen (H2)/natural gas (NG) mixtures or pure hydrogen in gas-fired power plants poses a lower carbon footprint instead of the regular 100% NG fuel. Reducing carbon emissions (CO2) in electricity production is fast gaining huge traction in gas power plants, as the attention is shifting from soon eradicated coal power plants to low carbon power plants. Increased interest in the hydrogen economy has further aroused discussions for hydrogen to replace natural gas. This paper evaluates the impact of hydrogen mixtures on existing power plants in three countries: Denmark, Germany, and the United Kingdom. The investigation is carried out using energy, exergy, and economic analysis to depict implications of the various mixtures on each of the power plants. The simulation of the power plants was performed using Ebsilon software, while the calculations of CO2, and NOx emissions were carried out with the aid of the Cantera software and the exergy-based analysis was computed in Excel VBA. The analyzed mixtures of H2/NG presented advantages in all the power plants studied such as lower CO2 emissions, higher energetic and exergetic efficiencies, and, therefore, lower mass flowrates of the fuel mixture. However, NOx discharge, levelized fuel cost (except in the Viborg power plant), and volumetric flowrate increased drastically. Conclusions of this paper will enlighten readers on the technological and economic constraints of using H2-NG mixtures in gas-fired power plants.
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Schemenau, Wolfgang, and Ulrich Häuser. "The Extension of Gas Turbine Power Plants to Combined Cycle Power Stations." In ASME 1986 International Gas Turbine Conference and Exhibit. American Society of Mechanical Engineers, 1986. http://dx.doi.org/10.1115/86-gt-64.

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In industrial countries as well as in developing countries there is a continuous growth of electricity consumption. The normal way to meet these requirements is the stepwise extension of electricity producing plants. In countries where clean fuel is available at acceptable prices the advantages of combined cycle plants in terms of efficiency and of smooth meeting the requirements can be used. The following essay concentrates on the influences of design criterias and ambient conditions on efficiency, output and plant cost for the type of CCP which is most frequently excecuted. As a result of an optimization an executed plant is described also with regard to lay out, required space and erection time.
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Tuccillo, R., G. Fontana, and E. Jannelli. "Coal-Derived Gas Utilization in Combined Gas-Steam Cycle Power Plants." In ASME 1990 International Gas Turbine and Aeroengine Congress and Exposition. American Society of Mechanical Engineers, 1990. http://dx.doi.org/10.1115/90-gt-366.

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In this paper, a general analysis of combined gas-steam cycles for power plants firing with both hydrocarbons and coal derived gas is reported. The purpose of this paper is to study the influence on power plants performance of different kind of fuels and to evaluate the most significant parameters of both gas and combined cycle. Results are presented for plant overall efficiency and net specific work, steam to gas mass flow ratio, dimensionless gas turbine specific speed and diameter, CO2 emissions etc., as functions of gas cycle pressure ratio and of the combustion temperature. Furthermore, for an existing power plant with a 120 MW gas turbine, the authors try to establish in which measure the combined cycle characteristic parameters, the gas turbine operating conditions, and the heat recovery steam generator efficiency, are modified by using synthetic fuels of different composition and calorific value. The influence is also analyzed either of bottoming steam cycle saturation pressure or — in a dual pressure steam cycle — of dimensionless fraction of steam mass flow in high pressure stream. The acquired results seem to constitute useful information on the criteria for the optimal design of a new integrated coal gasification combined cycle (IGCC) power plant.
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Hejazi, Amin, and Habib Rajabi Mashhadi. "Effects of Natural Gas network on optimal operation of gas-fired power plants." In 2016 6th Conference on Thermal Power Plants (CTPP). IEEE, 2016. http://dx.doi.org/10.1109/ctpp.2016.7483061.

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Ganjikunta, Jaya. "Design Considerations for Syngas Turbine Power Plants." In ASME 2015 Gas Turbine India Conference. American Society of Mechanical Engineers, 2015. http://dx.doi.org/10.1115/gtindia2015-1261.

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Market demands such as generating power at lower cost, increasing reliability, providing fuel flexibility, increasing efficiency and reducing emissions have renewed the interest in Integrated Gasification Combined Cycle (IGCC) plants in the Indian refinery segment. This technology typically uses coal or petroleum coke (petcoke) gasification and gas turbine based combined cycle systems as it offers potential advantages in reducing emissions and producing low cost electricity. Gasification of coal typically produces syngas which is a mixture of Hydrogen (H) and Carbon Monoxide (CO). Present state of gas turbine technology facilitates burning of low calorific fuels such as syngas and gas turbine is the heart of power block in IGCC. Selecting a suitable gas turbine for syngas fired power plant application and optimization in integration can offer the purchaser savings in initial cost by avoiding oversizing as well as reduction in operating cost through better efficiency. This paper discusses the following aspects of syngas turbine IGCC power plant: • Considerations in design and engineering approach • Review of technologies in syngas fired gas turbines • Design differences of syngas turbines with respect to natural gas fired turbines • Gas turbine integration with gasifier, associated syngas system design and materials • Syngas safety, HAZOP and Hazardous area classification • Retrofitting of existing gas turbines suitable for syngas firing • Project execution and coordination at various phases of a project This paper is based on the experience gained in the recently executed syngas fired gas turbine based captive power plant and IGCC plant. This experience would be useful for gas turbine technology selection, integration of gas turbine in to IGCC, estimating engineering efforts, cost savings, cycle time reduction, retrofits and lowering future syngas based power plant project risks.
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Yadav, R., Sunil Kumar Jumhare, Pradeep Kumar, and Samir Saraswati. "Thermodynamic Analysis of Intercooled Gas-Steam Combined and Steam Injected Gas Turbine Power Plants." In ASME Turbo Expo 2004: Power for Land, Sea, and Air. ASMEDC, 2004. http://dx.doi.org/10.1115/gt2004-54097.

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The current emphasis on the development of gas turbine related power plants such as combined and steam injected is on increasing the plant efficiency and specific work while minimizing the cost of power production per kW and emission. The present work deals with the thermodynamic analysis of intercooled (both surface and evaporative) gas/steam combined and steam injected cycle power plants. The intercooling has a beneficial effect on both plant efficiency and specific work if the optimum intercooling pressure is chosen between 3 and 4. The evaporative intercooler is superior to surface type with reference to plant efficiency and specific work.
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Reports on the topic "Gas power plants"

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Arbaje, Paul, and Mark Specht. Gas Malfunction: Calling into Question the Reliability of Gas Power Plants. Union of Concerned Scientists, January 2024. http://dx.doi.org/10.47923/2024.15312.

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While the United States has roughly doubled its investments in clean energy over the past 10 years, the power grid is still predominantly reliant on natural gas; gas plants provided 43 percent of generating capacity in 2022. This heavy reliance on gas plants, coupled with an assumption that gas plants are more reliable than they actually are, is a vulnerability for the power grid and for consumers. As recent evidence has shown, the US fleet of gas plants is susceptible to large-scale failures during extreme weather. For example, recent winter storms in Texas and the Southeast knocked unprecedented portions of the fleet offline, ultimately leading to rolling blackouts for millions of people. Heat waves and droughts have also significantly interfered with gas plant operations. As the impacts of climate change intensify, extreme weather events are becoming more frequent and more severe, increasing the threat to gas plants and, in turn, to the reliability of the power grid. Given these growing challenges, we must reassess the role of this resource in ensuring grid reliability.
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Marinkovic, Catalina, and Adrien Vogt-Schilb. Is Energy Planning Consistent with Climate Goals? Assessing Future Emissions from Power Plants in Latin America and the Caribbean. Inter-American Development Bank, October 2023. http://dx.doi.org/10.18235/0005183.

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At least ten Latin American and Caribbean countries have pledged to achieve carbon neutrality. Has electricity planning in the region evolved towards reaching these goals? We compare power generation capacity in 2023 to announced plans in 2019. We then estimate committed emissions from existing and planned power plants that is emissions that would result from the normal operations of these plants during their typical lifetime and compare them to emissions from power generation in published IPCC scenarios. We find that fossil fuel planned capacity has decreased by 47% since 2019, mainly due to the cancellation of 50% of coal and 40% of gas projects, compared to only 32% of renewable energy projects. But existing plants in the region will emit 6.7 GtCO2 during their lifespan, and if all planned plants are built, they will add 4.9 GtCO2, totaling 11.6 GtCO2, exceeding median carbon budgets for 1.5 and 2C-consistent IPCC pathways (2.3 and 4.3 GtCO2). Natural gas power plants are the largest contributor to existing (62%) and planned (75%) emissions (versus 24% and 23% for coal). We evaluate emissions reduction strategies to achieve carbon budgets. Assuming no new coal plants comes into operation, announced gas and oil projects are canceled at the same rate as in the past four years, all fossil fueled plant lifetimes are reduced by 10 years, and all new natural gas displaces existing coal, committed emissions fall by 59%, almost meeting the 2C budget, but still twice as large as the median 1.5C budget. Our results suggest that while progress is being made, energy planning in the region is not yet consistent with global climate goals as reflected by the IPCC scenario database.
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Skone, Timothy J., Greg Schivley, Matt Jamieson, Joe Marriott, Greg Cooney, James Littlefield, Michele Mutchek, Michelle Krynock, and Chung Yan Shih. Life Cycle Analysis: Natural Gas Combined Cycle (NGCC) Power Plants. Office of Scientific and Technical Information (OSTI), April 2018. http://dx.doi.org/10.2172/1562914.

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Sudhoff, F. A., and G. Steinfeld. Intermediate-sized natural gas fueled carbonate fuel cell power plants. Office of Scientific and Technical Information (OSTI), April 1993. http://dx.doi.org/10.2172/10116392.

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Sudhoff, F. A., and D. K. Fleming. Intermediate-sized natural gas fueled carbonate fuel cell power plants. Office of Scientific and Technical Information (OSTI), April 1994. http://dx.doi.org/10.2172/10116397.

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Cvetic, Patricia, Kyle Buchheit, Norma Kuehn, Alex Zoelle, Mark Woods, Gregory Hackett, and Timothy Fout. Natural Gas Combined Cycle (NGCC) Power Plants with Carbon Capture and Exhaust Gas Recycle (EGR). Office of Scientific and Technical Information (OSTI), October 2023. http://dx.doi.org/10.2172/2251495.

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Kuehn, Norma J., Kajal Mukherjee, Paul Phiambolis, Lora L. Pinkerton, Elsy Varghese, and Mark C. Woods. Current and Future Technologies for Natural Gas Combined Cycle (NGCC) Power Plants. Office of Scientific and Technical Information (OSTI), June 2013. http://dx.doi.org/10.2172/1490262.

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Leptinsky, Sarah, Tommy Schmitt, Alex Zoelle, Sally Homsy, Mark Woods, Travis Shultz, Jeff Hoffmann, and Gregory Hackett. Cost and Performance Projections for Coal- and Natural Gas-Fired Power Plants. Office of Scientific and Technical Information (OSTI), May 2023. http://dx.doi.org/10.2172/1988750.

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Jeffrey C. Quick, David E. Tabet, Sharon Wakefield, and Roger L. Bon. Optimizing Techology to Reduce Mercury and Acid Gas Emissions from Electric Power Plants. Office of Scientific and Technical Information (OSTI), January 2004. http://dx.doi.org/10.2172/909152.

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Jeffrey C. Quick, David E. Tabet, Sharon Wakefield, and Roger L. Bon. Optimizing Technology to Reduce Mercury and Acid Gas Emissions from Electric Power Plants. Office of Scientific and Technical Information (OSTI), July 2004. http://dx.doi.org/10.2172/909153.

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