scholarly journals Feasibility study on HYSOL CSP

2016 ◽  
Vol 13 (1) ◽  
Keyword(s):  
Power Generation ◽  
High Temperature ◽  
Natural Gas ◽  
Economic Analysis ◽  
Molten Salt ◽  
Gas Turbines ◽  
Combined Cycle ◽  
Economic Feasibility ◽  
Solar Irradiation ◽  
Firm Power

Concentrating Solar Power (CSP) plants utilize thermal conversion of direct solar irradiation. A trough or tower configuration focuses solar radiation and heats up oil or molten salt that subsequently in high temperature heat exchangers generate steam for power generation. High temperature molten salt can be stored and the stored heat can thus increase the load factor and the usability for a CSP plant, e.g. to cover evening peak demand. In the HYSOL concept (HYbrid SOLar) such configuration is extended further to include a gas turbine fuelled by upgraded biogas or natural gas. The optimised integrated HYSOL concept, therefore, becomes a fully dispatchable (offering firm power) and fully renewable energy source (RES) based power supply alternative, offering CO2-free electricity in regions with sufficient solar resources. The economic feasibility of HYSOL configurations is addressed in this paper. The analysis is performed from a socio- and private- economic perspective. In the socio-economic analysis, the CO2 free HYSOL alternative is discussed relative to conventional reference firm power generation technologies. In particular the HYSOL performance relative to new power plants based on natural gas (NG) such as open cycle or combined cycle gas turbines (OCGT or CCGT) are in focus. In the corporate-economic analysis the focus is on the uncertain technical and economic parameters. The core of the analyses is based on the LCOE economic indicator. In the corporate economic analysis, NPV and IRR are furthermore used to assess the feasibility. The feasibility of renewable based HYSOL power plant configurations attuned to specific electricity consumption patterns in selected regions with promising solar energy potentials are discussed.

Past, Present and Future of Combined Cycle Power Plants: From an A/E’s Perspective

2001 ◽  
Author(s):  
Anup Singh
Keyword(s):  
Power Generation ◽  
Natural Gas ◽  
Gas Turbine ◽  
Rapid Growth ◽  
Gas Turbines ◽  
Power Plants ◽  
Combined Cycle ◽  
Electrical Transmission ◽  
Capital Costs ◽  
The U.S

In the 1970s, power generation from gas turbines was minimal. Gas turbines in those days were run on fuel oil, since there was a so-called “natural gas shortage”. The U.S. Fuel Use Act of 1978 essentially disallowed the use of natural gas for power generation. Hence there was no incentive on the part of gas turbine manufacturers to invest in the development of gas turbine technology. There were many regulatory developments in the 1980s and 1990s, which led to the rapid growth in power generation from gas turbines. These developments included Public Utility Regulatory Policy Act of 1978 (encouraging cogeneration), FERC Order 636 (deregulating natural gas industry), Energy Policy Act of 1992 (creating EWGs and IPPs) and FERC Order 888 (open access to electrical transmission system). There was also a backlash from excessive electric rates due to high capital recovery of nuclear and coal-fired plant costs caused by tremendous cost increase resulting from tightening NRC requirements for nuclear plants and significant SO2/NOx/other emissions controls required for coal-fired plants. During this period, rapid technology developments took place in the metallurgy, design, efficiency, and reliability of gas turbines. In addition, U.S. DOE contributed to these developments by encouraging research and development efforts in high temperature and high efficiency gas turbines. Today we are seeing a tremendous explosion of power generating facilities by electric utilities and Independent Power Producers (IPPs). A few years ago, Merchant Power (generation without power purchase agreements) was unheard of. Today it is growing at a very fast pace. Can this rapid growth be sustained? The paper will explore the factors that will play a significant role in the future growth of gas turbine-based power generation in the U.S. The paper will also discuss the methods and developments that could decrease the capital costs of gas turbine power plants resulting in the lowest cost generation compared to other power generation technologies.

Integration of Post-Combustion Capture and Reinjection Plant to Power Generation Cycle Using CO2-Rich Natural Gas in Offshore Oil and Gas Installation

2019 ◽  
Vol 965 ◽  
pp. 49-58 ◽  
Author(s):  
Raquel de Pádua Fernandes Silva ◽  
José Luiz de Medeiros ◽  
Ofélia de Queiroz Fernandes Araújo
Keyword(s):  
Power Generation ◽  
Natural Gas ◽  
Oil Recovery ◽  
Gas Turbines ◽  
Power Efficiency ◽  
Oil And Gas ◽  
Combined Cycle ◽  
Simple Cycle ◽  
Total Efficiency ◽  
Aspen Hysys

The use of CO2-rich natural gas (%CO2 ≈ 20%mol) for power generation in offshore hubs results in simpler upgrade process, while imposes an extra challenge to mitigate emissions. Power generation via combined cycle configurations and post-combustion capture with CO2 reinjection are investigated for carbon-footprint reduction, while increasing gas export and oil production, respectively. The processes are simulated using Aspen HYSYS software and compared to currently installed simple cycle configuration in terms of footprint, weight, power, efficiency and CO2 emissions. The combined cycle including two gas turbines and one single-pressure steam cycle (CC 2:1:1) results in the most favorable power system, having 53% efficiency, 476.8 gCO2/kWh emissions and similar dimensions compared to the simple cycle. The integration of a post-combustion capture sending the CO2 for enhanced oil recovery results in 241 gCO2/kWh for the CC 2:1:1 and 251 gCO2/kWh for the simple cycle, without great impacts in total efficiency. The CC 2:1:1 with post-combustion capture presents higher net efficiency, lower dimensions and greater economic advantages, enabling emissions reduction without having significant impacts on the power generation.

Design and Operational Aspects of Gas and Steam Turbines for the Novel Solar Hybrid Combined Cycle SHCC®

2010 ◽  
Author(s):  
Stephan Heide ◽  
Uwe Gampe ◽  
Ulrich Orth ◽  
Markus Beukenberg ◽  
Bernd Gericke ◽  
...  
Keyword(s):  
High Temperature ◽  
Power Plant ◽  
Gas Turbine ◽  
Heat Input ◽  
Gas Turbines ◽  
Power Plants ◽  
Combined Cycle ◽  
Solar Irradiation ◽  
Test Field ◽  
Solar Heat

Solar hybrid power plants are characterized by a combination of heat input both of high temperature solar heat and heat from combustion of gaseous or liquid fuel which enables to supply the electricity market according to its requirements and to utilize the limited and high grade natural resources economically. The SHCC® power plant concept integrates the high temperature solar heat into the gas turbine process and in addition — depending on the scheme of the process cycle — downstream into the steam cycle. The feed-in of solar heat into the gas turbine is carried out between compressor outlet and combustor inlet either by direct solar thermal heating of the pressurized air inside the receivers of the solar tower or by indirectly heating via interconnection of a heat transfer fluid. Thus, high shares of solar heat input referring to the total heat input of more than 60% in design point can be achieved. Besides low consumption of fossil fuels and high efficiency, the SHCC® concept is aimed for a permanent availability of the power plant capacity due to the possible substitution of solar heat by combustion heat during periods without sufficient solar irradiation. In consequence, no additional standby capacity is necessary. SHCC® can be conducted with today’s power plant and solar technology. One of the possible variants has already been demonstrated in the test field PSA in Spain using a small capacity gas turbine with location in the head of the solar tower for direct heating of the combustion air. However, the authors present and analyze also alternative concepts for power plants of higher capacity. Of course, the gas turbine needs a design which enables the external heating of the combustion air. Today only a few types of gas turbines are available for SHCC® demonstration. But these gas turbines were not designed for solar hybrid application at all. Thus, the autors present finally some reflections on gas turbine parameters and their consequences for SHCC® as basis for evaluation of potentials of SHCC®.

Relation of Air-to-Fuel and Hydrogen-to-Carbon Ratios to Flue Gases in Common Power Generation Systems

2009 ◽  
Author(s):  
Michael D. Costarell
Keyword(s):  
Power Generation ◽  
Natural Gas ◽  
Flue Gas ◽  
Gas Turbines ◽  
Three Dimensional ◽  
Two Dimensions ◽  
Combined Cycle ◽  
Hydrocarbon Fuels ◽  
Three Dimensions ◽  
Pure Hydrogen

For traditional power generation fuels, the flue gas components can be viewed as continuums based on the air-to-fuel (A:F) and hydrogen-to-carbon (H:C) ratios. This paper defines those continuums for common hydrocarbon fuels (coal, natural gas and oil), in the three most common combustion systems (boilers, reciprocating engines, and gas turbines). Plotted vs. A:F in two dimensions, and then plotted vs. A:F and H:C in three dimensions, overall trends are developed for flue gas carbon dioxide and oxygen. The discussion then compares the calculation of A:F ratios in natural gas combined cycle plants with those in integrated gasification combined cycle plants. Hydrocarbon fuels with no entrained oxygen trend well in both two- and three-dimensional plots, while pure hydrogen and syngas processes do not.

scholarly journals Technical and Economic Analysis of Repowering a Coal-Fired Power Plant

1999 ◽  
Author(s):  
Joseph Roy-Aikins ◽  
Reshleu J. Rampershad
Keyword(s):  
Economic Analysis ◽  
Steam Turbine ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Electrical Power ◽  
Economic Benefits ◽  
Combined Cycle ◽  
Economic Feasibility ◽  
Power Station ◽  
Power Stations

Owing to an abundance of coal reserves, about 92 percent of the electrical power produced in South Africa is generated in central power stations fired on cheaply priced coal. With a few power stations approaching the end of their design life, the question arises as to what to do with these outdated and inefficient plants. Retrofitting or repowering a station with gas turbines is one option being considered. As a case study, this paper investigates the technical and economic feasibility of repowering the Arnot power station to convert it to a combined cycle plant with increased capacity. This power station has six generating units, each of nominal capacity 350 MW and of average age 25 years. Four are in service, and the others are in reserve storage. Several repowering options were considered and the proposed re-design is parallel repowering, where additional steam for a steam turbine is generated in a gas turbine heat recovery steam generator to supplement the steam generated in a coal-fired boiler. Since natural gas, the preferred fuel for gas turbines, is not readily available in the country, kerosene was used as gas turbine fuel. Consequently, the performance of the chosen gas turbine had to be re-evaluated. The output of each unit increased by 77 MW and the efficiency by 8 percentage points to 43 percent, after repowering. Repowering was feasible, technically. An economic analysis was required to determine the magnitude of the economic benefits of repowering, if any, and it turned out that the cost of electricity generated by the new technology was higher than that produced by the outgoing one. It was concluded, therefore, that repowering the steam turbine units with gas turbines fired on kerosene was uneconomical, for the performance level achieved.

scholarly journals Perspective on a Combustion-Free Gas Turbine to Meet Power Generation Needs in the 21st Century

1997 ◽  
Author(s):  
Colin F. McDonald
Keyword(s):  
Power Generation ◽  
Natural Gas ◽  
Gas Turbine ◽  
21St Century ◽  
Gas Turbines ◽  
High Efficiency ◽  
Electrical Power ◽  
Resource Depletion ◽  
Combined Cycle ◽  
Combustion Gas

The combustion gas turbine, operating in both simple and combined cycle modes, is rapidly becoming the preferred prime-mover for electrical power generation for both new plants, and in the repowering of old power stations. In replacing Rankine cycle plants the combustion gas turbine could become dominant in the power generation field early in the next century. Fired currently with natural gas, and later with gasified coal these gas turbines will operate for many decades with no concern about resource depletion. This paper addresses an extension of high efficiency gas turbine technology but uses a combustion and emission-free heat source, namely a high temperature gas cooled nuclear reactor. The motivation for this evolution is essentially twofold, 1) to introduce an environmentally benign plant that does not emit greenhouse gases, and 2) provide electrical power to nations that have no indigenous natural gas or coal supplies. This paper presents a confidence-building approach that eliminates risk towards the goal of making the nuclear gas turbine a reality in the 21st century.

scholarly journals Solar Integrated Anaerobic Digester: Energy Savings and Economics

Energies ◽  
2020 ◽  
Vol 13 (17) ◽  
pp. 4292
Author(s):  
Lidia Lombardi ◽  
Barbara Mendecka ◽  
Simone Fabrizi
Keyword(s):  
Anaerobic Digestion ◽  
Natural Gas ◽  
Economic Analysis ◽  
Thermal Energy ◽  
Economic Feasibility ◽  
Solar Thermal ◽  
Base Case ◽  
Economic Sustainability ◽  
Solar Thermal Energy ◽  
Solar Integration

Industrial anaerobic digestion requires low temperature thermal energy to heat the feedstock and maintain temperature conditions inside the reactor. In some cases, the thermal requirements are satisfied by burning part of the produced biogas in devoted boilers. However, part of the biogas can be saved by integrating thermal solar energy into the anaerobic digestion plant. We study the possibility of integrating solar thermal energy in biowaste mesophilic/thermophilic anaerobic digestion, with the aim of reducing the amount of biogas burnt for internal heating and increasing the amount of biogas, further upgraded to biomethane and injected into the natural gas grid. With respect to previously available studies that evaluated the possibility of integrating solar thermal energy in anaerobic digestion, we introduce the topic of economic sustainability by performing a preliminary and simplified economic analysis of the solar system, based only on the additional costs/revenues. The case of Italian economic incentives for biomethane injection into the natural gas grid—that are particularly favourable—is considered as reference case. The amount of saved biogas/biomethane, on an annual basis, is about 4–55% of the heat required by the gas boiler in the base case, without solar integration, depending on the different considered variables (mesophilic/thermophilic, solar field area, storage time, latitude, type of collector). Results of the economic analysis show that the economic sustainability can be reached only for some of the analysed conditions, using the less expensive collector, even if its efficiency allows lower biomethane savings. Future reduction of solar collector costs might improve the economic feasibility. However, when the payback time is calculated, excluding the Italian incentives and considering selling the biomethane at the natural gas price, its value is always higher than 10 years. Therefore, incentives mechanism is of great importance to support the economic sustainability of solar integration in biowaste anaerobic digestion producing biomethane.

Predicting Flameholding for Hydrogen and Natural Gas Flames at Gas Turbine Premixer Conditions

2016 ◽  
Vol 138 (12) ◽  
Author(s):  
Elliot Sullivan-Lewis ◽  
Vincent McDonell
Keyword(s):  
Power Generation ◽  
Natural Gas ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Experimental Studies ◽  
Temperature Variations ◽  
Auto Ignition ◽  
Chamber Temperature ◽  
Transient Events ◽  
Significant Effort

Lean-premixed gas turbines are now common devices for low emissions stationary power generation. By creating a homogeneous mixture of fuel and air upstream of the combustion chamber, temperature variations are reduced within the combustor, which reduces emissions of nitrogen oxides. However, by premixing fuel and air, a potentially flammable mixture is established in a part of the engine not designed to contain a flame. If the flame propagates upstream from the combustor (flashback), significant engine damage can result. While significant effort has been put into developing flashback resistant combustors, these combustors are only capable of preventing flashback during steady operation of the engine. Transient events (e.g., auto-ignition within the premixer and pressure spikes during ignition) can trigger flashback that cannot be prevented with even the best combustor design. In these cases, preventing engine damage requires designing premixers that will not allow a flame to be sustained. Experimental studies were conducted to determine under what conditions premixed flames of hydrogen and natural gas can be anchored in a simulated gas turbine premixer. Tests have been conducted at pressures up to 9 atm, temperatures up to 750 K, and freestream velocities between 20 and 100 m/s. Flames were anchored in the wakes of features typical of premixer passageways, including cylinders, steps, and airfoils. The results of this study have been used to develop an engineering tool that predicts under what conditions a flame will anchor, and can be used for development of flame anchoring resistant gas turbine premixers.

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