scholarly journals Thermal Energy Storage For Gas Turbine Power Augmentation

2019 ◽  
Vol 3 ◽  
pp. 592-608
Author(s):  
Vasilis Gkoutzamanis ◽  
Anastasia Chatziangelidou ◽  
Theofilos Efstathiadis ◽  
Anestis Kalfas ◽  
Alberto Traverso ◽  
...  
Keyword(s):  
Energy Storage ◽  
Gas Turbine ◽  
Thermal Energy ◽  
Thermal Energy Storage ◽  
Combined Cycle ◽  
Inlet Temperature ◽  
Air Cooling ◽  
Ambient Conditions ◽  
Air Inlet ◽  
Conventional Cooling

This work is concerned with the investigation of thermal energy storage (TES) in relation to gas turbine inlet air cooling. The utilization of such techniques in simple gas turbine or combined cycle plants leads to improvement of flexibility and overall performance. Its scope is to review the various methods used to provide gas turbine power augmentation through inlet cooling and focus on the rising opportunities when these are combined with thermal energy storage. The results show that there is great potential in such systems due to their capability to provide intake conditioning of the gas turbine, decoupled from the ambient conditions. Moreover, latent heat TES have the strongest potential (compared to sensible heat TES) towards integrated inlet conditioning systems, making them a comparable solution to the more conventional cooling methods and uniquely suitable for energy production applications where stabilization of GT air inlet temperature is a requisite. Considering the system’s thermophysical, environmental and economic characteristics, employing TES leads to more than 10% power augmentation.

scholarly journals Preliminary investigation of thermal behaviour of PCM based latent heat thermal energy storage

2018 ◽  
Vol 32 ◽  
pp. 01017
Author(s):  
Octavian G. Pop ◽  
Lucian Fechete Tutunaru ◽  
Florin Bode ◽  
Mugur C. Balan
Keyword(s):  
Energy Consumption ◽  
Energy Storage ◽  
Latent Heat ◽  
Thermal Energy ◽  
Thermal Energy Storage ◽  
Cooling System ◽  
Air Cooling ◽  
Air Velocity ◽  
Air Inlet ◽  
Air Cooling System

Solid-liquid phase change is used to accumulate and release cold in latent heat thermal energy storage (LHTES) in order to reduce energy consumption of air cooling system in buildings. The storing capacity of the LHTES depends greatly on the exterior air temperatures during the summer nights. One approach in intensifying heat transfer is by increasing the air’s velocity. A LHTES was designed to be integrated in the air cooling system of a building located in Bucharest, during the month of July. This study presents a numerical investigation concerning the impact of air inlet temperatures and air velocity on the formation of solid PCM, on the cold storing capacity and energy consumption of the LHTES. The peak amount of accumulated cold is reached at different air velocities depending on air inlet temperature. For inlet temperatures of 14°C and 15°C, an increase of air velocity above 50% will not lead to higher amounts of cold being stored. For Bucharest during the hottest night of the year, a 100 % increase in air velocity will result in 5.02% more cold being stored, at an increase in electrical energy consumption of 25.30%, when compared to the reference values.

Performance Evaluation of a Gas Turbine Operating Noncontinuously with its Inlet Air Cooled Through an Aquifer Thermal Energy Storage

2006 ◽  
Vol 129 (2) ◽  
pp. 117-124 ◽  
Author(s):  
Farhad Behafarid ◽  
Mehdi N. Bahadori
Keyword(s):  
Energy Storage ◽  
Thermal Energy ◽  
Thermal Energy Storage ◽  
Power Output ◽  
Gas Turbines ◽  
Peak Power ◽  
Combined Cycle ◽  
Air Cooling ◽  
Aquifer Thermal Energy Storage ◽  
Cooling Methods

The power output of gas turbines (GT) reduces greatly with the increase of the inlet air temperature. This is a serious problem because gas turbines have been used traditionally to provide electricity during the peak power demands, and the peak power demands in many areas occur on summer afternoons. An aquifer thermal energy storage (ATES) was employed for cooling of the inlet air of the GT. Water from a confined aquifer was cooled in winter and was injected back into the aquifer. The stored chilled water was withdrawn in summer to cool the GT inlet air. The heated water was then injected back into the aquifer. A 20MW GT power plant with 6 and 12h of operation per day, along with a two-well aquifer, was considered for analysis. The purpose of this investigation was to estimate the GT performance improvement. The conventional inlet air cooling methods such as evaporative cooling, fogging and absorption refrigeration were studied and compared with the ATES system. It was shown that for 6h of operation per day, the power output and efficiency of the GT on the warmest day of the year could be increased from 16.5 to 19.7MW and from 31.8% to 34.2%, respectively. The performance of the ATES system was the best among the cooling methods considered on the warmest day of the year. The use of ATES is a viable option for the increase of gas turbines power output and efficiency, provided that suitable confined aquifers are available at their sites. Air cooling in ATES is not dependent on the wet-bulb temperature and therefore can be used in humid areas. This system can also be used in combined cycle power plants.

scholarly journals Thermal energy storage in combined cycle power plants: comparing finite volume to finite element methods

2019 ◽  
Vol 113 ◽  
pp. 01001
Author(s):  
Vasilis G. Gkoutzamanis ◽  
Justin N. W. Chiu ◽  
Guillaume Martin ◽  
Anestis I. Kalfas
Keyword(s):  
Heat Transfer ◽  
Energy Storage ◽  
Flow Rate ◽  
Thermal Energy ◽  
Thermal Energy Storage ◽  
Thermal Power ◽  
Combined Cycle ◽  
Inlet Temperature ◽  
Rate Variation ◽  
Full Potential

The research in thermal energy storage (TES) systems has a long track record. However, there are several technical challenges that need to be overcome, to become omnipresent and reach their full potential. These include performance, physical size, weight and dynamic response. In many cases, it is also necessary to be able to achieve the foregoing at greater and greater scale, in terms of power and energy. One of the applications in which these challenges prevail is in the integration of a thermal energy storage with the gas turbine (GT) compressor inlet conditioning system in a combined cycle power plant. The system is intended to provide either GT cooling or heating, based on the operational strategy of the plant. As a contribution to tackle the preceding, this article describes a series of 3-dimensional (3D) numerical simulations, employing different Computational Fluid Dynamics (CFD) methods, to study the transient effects of inlet temperature and flow rate variation on the performance of an encapsulated TES with phase change materials (PCM). A sensitivity analysis is performed where the heat transfer fluid (HTF) temperature varies from -7°C to 20°C depending on the operating mode of the TES (charging or discharging). The flow rate ranges from 50% to 200% of the nominal inflow rate. Results show that all examined cases lead to instant thermal power above 100kWth. Moreover, increasing the flow rate leads to faster solidification and melting. The increment in each process depends on the driving temperature difference between the encapsulated PCM and the HTF inlet temperature. Lastly, the effect of the inlet temperature has a larger effect as compared to the mass flow rate on the efficiency of the heat transfer of the system.

Thermal Energy Storage and Inlet Air Cooling for Combined Cycle

1994 ◽  
Author(s):  
Jerry Ebeling ◽  
Robert Balsbaugh ◽  
Steven Blanchard ◽  
Lawrence Beaty
Keyword(s):  
Energy Storage ◽  
Thermal Energy ◽  
Thermal Energy Storage ◽  
Combined Cycle ◽  
Public Works ◽  
Air Cooling ◽  
Generation Plant ◽  
Cooling Coils ◽  
Ice Production ◽  
And Storage

The paper will discuss the application of Thermal Energy Storage (TES) using ice and inlet air cooling at the Fayetteville (North Carolina, USA) Public Works Commission (PWC) Butler-Warner Generation Plant. The Butler-Warner Generating Plant consists of eight General Electric Frame 5 combustion turbines and a single steam turbine. Six of the combustion turbines exhaust through three Heat Recovery Steam Generators (HRSG). The project consisted of modifying the inlets of all eight combustion turbines to accommodate plate fin cooling coils and new air filters; and the design and construction of the TES ice production and storage facilities. A feasibility study was completed in June 1992. Detail designed began in August 1992. Initial operation was June 1993. The modifications have been completed and the plant has experienced a 29% capacity increase as a result of the project.

scholarly journals Gas Turbine/Solar Parabolic Trough Hybrid Designs

2011 ◽  
Author(s):  
Craig S. Turchi ◽  
Zhiwen Ma ◽  
Michael Erbes
Keyword(s):  
Energy Storage ◽  
Natural Gas ◽  
Gas Turbine ◽  
Thermal Energy ◽  
Thermal Energy Storage ◽  
High Reliability ◽  
Thermal Power ◽  
Combined Cycle ◽  
Parabolic Trough ◽  
Combined Cycle Plant

A strength of parabolic trough concentrating solar power (CSP) plants is the ability to provide reliable power by incorporating either thermal energy storage or backup heat from fossil fuels. Yet these benefits have not been fully realized because thermal energy storage remains expensive at trough operating temperatures and gas usage in CSP plants is less efficient than in dedicated combined cycle plants. For example, while a modern combined cycle plant can achieve an overall efficiency in excess of 55%; auxiliary heaters in a parabolic trough plant convert gas to electricity at below 40%. Thus, one can argue the more effective use of natural gas is in a combined cycle plant, not as backup to a CSP plant. Integrated solar combined cycle (ISCC) systems avoid this pitfall by injecting solar steam into the fossil power cycle; however, these designs are limited to about 10% total solar enhancement. Without reliable, cost-effective energy storage or backup power, renewable sources will struggle to achieve a high penetration in the electric grid. This paper describes a novel gas turbine / parabolic trough hybrid design that combines solar contribution of 57% and higher with gas heat rates that rival that for combined cycle natural gas plants. The design integrates proven solar and fossil technologies, thereby offering high reliability and low financial risk while promoting deployment of solar thermal power.

Techno-Economic Optimization of a Combined Cycle Combined Heat and Power Plant With Integrated Heat Pump and Low-Temperature Thermal Energy Storage

2020 ◽  
Author(s):  
Jose Garcia ◽  
Vincent Smet ◽  
Rafael Guedez ◽  
Alessandro Sorce
Keyword(s):  
Energy Storage ◽  
Power Plant ◽  
Thermal Energy ◽  
Thermal Energy Storage ◽  
Net Present Value ◽  
Heat Pumps ◽  
Combined Cycle ◽  
Electricity Production ◽  
Ambient Conditions ◽  
Market Conditions

Abstract The present study presents a techno-economic analysis of a novel power plant layout developed to increase the dispatch flexibility of a Combined Cycle Gas Turbine (CCGT) coupled to a District Heating Network (DHN). The layout includes the incorporation of high temperature heat pumps (HP) and thermal energy storage (TES). A model for optimizing the short-term dispatch strategy of such system has been developed to maximize its operational profit. The constraints and boundary conditions considered in the study include hourly demand and price of electricity and heat, ambient conditions and CO2 emission allowances. To assess the techno-economic benefit of the new layout, a year of operation was simulated for a power plant in Turin, Italy. Furthermore, different layout configurations and critical size-related parameters were considered. Finally, a sensitivity analysis was made to assess the performance under different market scenarios. The results show that it is indeed beneficial, under the assumed market conditions, to integrate a HP in a CCGT plant coupled to a DHN, and that it remains profitable to do so under a variety of market scenarios. The best results for the assumed market conditions were found when integrating a 15 MWth capacity HP in the 400 MWel CCGT-CHP. For this case study, the investment in the HP would yield a net present value (NPV) of 1.22 M€ and an internal rate of return (IRR) of 3.04% for a lifetime of 20 years. An increase was shown also in operational flexibility with 0.14% of the electricity production shifted while meeting the same heating demand. Additionally, it was found that the TES makes the system even more flexible, but does not make up for the extra investment.

scholarly journals Flexible Electricity Dispatch of an Integrated Solar Combined Cycle through Thermal Energy Storage and Hydrogen Production

Thermo ◽  
2021 ◽  
Vol 1 (1) ◽  
pp. 106-121
Author(s):  
Miguel Ángel Reyes-Belmonte ◽  
Alejandra Ambrona-Bermúdez ◽  
Daniel Calvo-Blázquez
Keyword(s):  
Energy Storage ◽  
Thermal Energy ◽  
Thermal Energy Storage ◽  
Hydrogen Generation ◽  
Combined Cycle ◽  
Medium Temperature ◽  
Cost Of Electricity ◽  
Demand Curves ◽  
Hydrogen Plant ◽  
Demand Coverage

In this work, the flexible operation of an Integrated Solar Combined Cycle (ISCC) power plant has been optimized considering two different energy storage approaches. The objective of this proposal is to meet variable users’ grid demand for an extended period at the lowest cost of electricity. Medium temperature thermal energy storage (TES) and hydrogen generation configurations have been analyzed from a techno-economic point of view. Results found from annual solar plant performance indicate that molten salts storage solution is preferable based on the lower levelized cost of electricity (0.122 USD/kWh compared to 0.158 USD/kWh from the hydrogen generation case) due to the lower conversion efficiencies of hydrogen plant components. However, the hydrogen plant configuration exceeded, in terms of plant availability and grid demand coverage, as fewer design constraints resulted in a total demand coverage of 2155 h per year. It was also found that grid demand curves from industrial countries limit the deployment of medium-temperature TES systems coupled to ISCC power plants, since their typical demand curves are characterized by lower power demand around solar noon when solar radiation is higher. In such scenarios, the Brayton turbine design is constrained by noon grid demand, which limits the solar field and receiver thermal power design.

Advanced and Transformational Hydrogen Turbines for Integrated Gasification Combined Cycles

2016 ◽  
Author(s):  
Walter W. Shelton ◽  
Robin W. Ames ◽  
Richard A. Dennis ◽  
Charles W. White ◽  
John E. Plunkett ◽  
...  
Keyword(s):  
Gas Turbine ◽  
Carbon Capture ◽  
Combined Cycle ◽  
Plant Performance ◽  
System Level ◽  
Inlet Temperature ◽  
Air Cooling ◽  
Reference Case ◽  
Advanced Technologies ◽  
Integrated Gasification

The U.S. Department of Energy’s (DOE) provides a worldwide leadership role in the development of advanced fossil fuel-based energy conversion technologies, with a focus on electric power generation with carbon capture and storage (CCS). As part of DOE’s Office of Fossil Energy, the National Energy Technology Laboratory (NETL) implements research, development, and demonstration (RD&D) programs that address the challenges of reducing greenhouse gas emissions. To meet these challenges, NETL evaluates advanced power cycles that will maximize system efficiency and performance, while minimizing CO2 emissions and the costs of CCS. NETL’s Hydrogen Turbine Program has sponsored numerous R&D projects in support of Advanced Hydrogen Turbines (AHT). Turbine systems and components targeted for development include combustor technology, materials research, enhanced cooling technology, coatings development, and more. The R&D builds on existing gas turbine technologies and is intended to develop and test the component technologies and subsystems needed to validate the ability to meet the Turbine Program goals. These technologies are key components of AHTs, which enable overall plant efficiency and cost of electricity (COE) improvements relative to an F-frame turbine-based Integrated Gasification Combined Cycle (IGCC) reference plant equipped with carbon capture (today’s state-of-the-art). This work has also provided the basis for estimating future IGCC plant performance based on a Transformational Hydrogen Turbine (THT) with a higher turbine inlet temperature, enhanced material capabilities, reduced air cooling and leakage, and higher pressure ratios than the AHT. IGCC cases from using system-level AHT and THT gas turbine models were developed for comparisons with an F-frame turbine-based IGCC reference case and for an IGCC pathway study. The IGCC pathway is presented in which the reference case (i.e. includes F-frame turbine) is sequentially-modified through the incorporation of advanced technologies. Advanced technologies are considered to be either 2nd Generation or Transformational, if they are anticipated to be ready for demonstration by 2025 and 2030, respectively. The current results included the THT, additional potential transformational technologies related to IGCC plant sections (e.g. air separation, gasification, gas cleanup, carbon capture, NOx reduction) are being considered by NETL and are topics for inclusion in future reports.

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