Thermoeconomic Analysis of Gas Turbine Plants With Fuel Decarbonization and Carbon Dioxide Sequestration

2003 ◽  
Vol 125 (4) ◽  
pp. 947-953 ◽  
Author(s):  
M. Bozzolo ◽  
M. Brandani ◽  
A. Traverso ◽  
A. F. Massardo
Keyword(s):  
Carbon Dioxide ◽  
Gas Turbine ◽  
Capital Investment ◽  
Carbon Tax ◽  
Carbon Dioxide Sequestration ◽  
Production Costs ◽  
Fuel Gas ◽  
Total Capital ◽  
Total Capital Investment ◽  
Water Gas

In this paper the thermoeconomic analysis of gas turbine plants with fuel decarbonization and carbon dioxide sequestration is presented. The study focuses on the amine (MEA) decarbonization plant layout and design, also providing economic data about the total capital investment costs of the plant. The system is fuelled with methane that is chemically treated through a partial oxidation and a water-gas shift reactor. CO2 is captured from the resulting gas mixture, using an absorbing solution of water and MEA that is continuously recirculated through an absorption tower and a regeneration tower: the decarbonized fuel gas is afterwards burned in the gas turbine. The heat required by CO2 sequestration is mainly recovered from the gas turbine exhausts and partially from the fuel treatment section. The reduction in efficiency and the increase in energy production costs due to fuel amine decarbonization is evaluated and discussed for different gas turbine sizes and technologies (microturbine, small size regenerated, aeroderivative, heavy duty). The necessary level of carbon tax for a conventional plant without a fuel decarbonization section is calculated and a comparison with the carbon exergy tax procedure is carried out, showing the good agreement of the results.

Thermoeconomic Analysis of a Gas Turbine Plant With Fuel Decarbonization and Carbon Dioxide Sequestration

2002 ◽  
Author(s):  
M. Bozzolo ◽  
M. Brandani ◽  
A. Traverso ◽  
A. F. Massardo
Keyword(s):  
Carbon Dioxide ◽  
Gas Turbine ◽  
Capital Investment ◽  
Carbon Tax ◽  
Carbon Dioxide Sequestration ◽  
Production Costs ◽  
Fuel Gas ◽  
Total Capital ◽  
Total Capital Investment ◽  
Water Gas

In this paper the thermoeconomic analysis of gas turbine plants with fuel decarbonisation and carbon dioxide sequestration is presented. The study focuses on the amine (MEA) decarbonisation plant lay-out and design, also providing economic data about the total capital investment costs of the plant. The system is fuelled with methane that is chemically treated through a partial oxidation and a water-gas shift reactor. CO2 is captured from the resulting gas mixture, using an absorbing solution of water and MEA that is continuously re-circulated through an absorption tower and a regeneration tower: the decarbonised fuel gas is afterwards burned in the gas turbine. The heat required by CO2 sequestration is mainly recovered from the gas turbine exhausts and partially from the fuel treatment section. The reduction in efficiency and the increase in energy production costs due to fuel amine decarbonisation is evaluated and discussed for different gas turbine sizes and technologies (microturbine, small size regenerated, aeroderivative, heavy duty). The necessary level of carbon tax for a conventional plant without a fuel decarbonisation section is calculated and a comparison with the Carbon Exergy Tax procedure is carried out, showing the good agreement of the results.

Gas Turbine Combined Cycle With CO2-Capture Using Auto-Thermal Reforming of Natural Gas

2000 ◽  
Author(s):  
Thormod Andersen ◽  
Hanne M. Kvamsdal ◽  
Olav Bolland
Keyword(s):  
Natural Gas ◽  
Gas Turbine ◽  
Process Integration ◽  
Combined Cycle ◽  
Co2 Removal ◽  
Gas Turbine Combustor ◽  
Chemical Absorption ◽  
Fuel Gas ◽  
The Impact ◽  
Water Gas

A concept for capturing and sequestering CO2 from a natural gas fired combined cycle power plant is presented. The present approach is to decarbonise the fuel prior to combustion by reforming natural gas, producing a hydrogen-rich fuel. The reforming process consists of an air-blown pressurised auto-thermal reformer that produces a gas containing H2, CO and a small fraction of CH4 as combustible components. The gas is then led through a water gas shift reactor, where the equilibrium of CO and H2O is shifted towards CO2 and H2. The CO2 is then captured from the resulting gas by chemical absorption. The gas turbine of this system is then fed with a fuel gas containing approximately 50% H2. In order to achieve acceptable level of fuel-to-electricity conversion efficiency, this kind of process is attractive because of the possibility of process integration between the combined cycle and the reforming process. A comparison is made between a “standard” combined cycle and the current process with CO2-removal. This study also comprise an investigation of using a lower pressure level in the reforming section than in the gas turbine combustor and the impact of reduced steam/carbon ratio in the main reformer. The impact on gas turbine operation because of massive air bleed and the use of a hydrogen rich fuel is discussed.

Up Close: Institut Max von Laue-Paul Langevin, An International Neutron Research Center

MRS Bulletin ◽  
1988 ◽  
Vol 13 (1) ◽  
pp. 19-24
Author(s):  
Bernd P. Maier
Keyword(s):  
United Kingdom ◽  
Nuclear Physics ◽  
Capital Investment ◽  
Materials Science ◽  
Experimental Program ◽  
Federal Republic Of Germany ◽  
Engineering Research ◽  
Max Von Laue ◽  
Total Capital ◽  
Total Capital Investment

The Institut Max von Laue-Paul Langevin (ILL) at Grenoble, France was formally founded in January 1967, with the signature of an intergovernmental convention between France and the Federal Republic of Germany. The aim was to provide the scientific community of the affiliated countries with a unique neutron beam facility applicable in fields such as the physics of condensed matter, chemistry, biology, nuclear physics, and materials science. The construction of the Institut and its high flux reactor was undertaken as a joint French-German project, with a total capital investment of 335 million French francs.The reactor first went critical in August 1971 and reached its full power of 57 MW for the first time in December 1971. The year 1972 saw the startup of the cold and hot sources, the first instruments, and the beginning of the experimental program.On January 1, 1973, the United Kingdom joined the Institut as a third equal partner, contributing its share to the total capital investment. In December 1986, an agreement on “Scientific Membership” for Spain was signed for a period of five years starting January 1, 1987. The ILL is a nontrading company under French civil law. The three countries are represented by the following associates: Kernforschungszentrum Karlsruhe GmbH (W. Germany), Centre National de la Recherche Scientifique (France), Commissariat à l'Energie Atomique (France), and Science and Engineering Research Council (United Kingdom). These associates are represented on a Steering Committee which establishes the general rules of the management of the ILL.

EVAL: A methodological approach to identify NPP total capital investment cost drivers and sensitivities

2018 ◽  
Vol 104 ◽  
pp. 190-202 ◽  
Author(s):  
Giovanni Maronati ◽  
Bojan Petrovic ◽  
Jurie J. Van Wyk ◽  
Matthew H. Kelley ◽  
Chelsea C. White
Keyword(s):  
Capital Investment ◽  
Methodological Approach ◽  
Cost Drivers ◽  
Total Capital ◽  
Investment Cost ◽  
Total Capital Investment

scholarly journals Combustion of Coal-Derived Fuel Gas in an Oxygen-Blown Pressurized Topping Combustor

1997 ◽  
Author(s):  
Peter D. J. Hoppesteyn ◽  
Jans Andries ◽  
Klaus R. G. Hein
Keyword(s):  
Carbon Dioxide ◽  
Gas Turbine ◽  
Flue Gas ◽  
Carbon Dioxide Concentration ◽  
The United States ◽  
Combined Cycle ◽  
Fluidised Bed ◽  
Successful Operation ◽  
Fuel Gas ◽  
System Pressure

Advanced integrated gasification combined cycle (IGCC) plants promise to be efficient and environmentally friendly systems to utilise solid fuels for the production of electricity and heat. An IGCC system consists of a gasifier, producing a low calorific value (LCV) fuel gas, and a gas turbine in which the LCV fuel gas is being combusted. At this time some demonstration IGCC plants have been commissioned in the United States and Europe. A sound understanding of the interaction between the gasifier and the gas turbine combustor is critical for successful operation of an IGCC system. Reliable theoretical and experimental information on the characteristics of the gas turbine as a whole and the combustor as such, leading to this information is needed prior to commercialisation of these IGCC systems. The combustion of natural gas in gas turbine combustors has been studied extensively. The combustion of coal-derived LCV fuel gas however has been studied in much less detail. To obtain more fundamental data on the combustion of LCV fuel gas, a 1.5 MW pressurised fluidised bed gasifier (PFBG) with a separate pressurised topping combustor (PTC) has been designed, built and operated at Delft University of Technology (The Netherlands). The maximum system pressure is 10 bar. Experiments have been performed at 8 bar, using recirculated flue gas, steam and oxygen as gasifying agents. The produced LCV fuel gas is combusted in an oxygen blown PTC. In this way a flue gas with a high carbon dioxide concentration can be obtained from which the carbon dioxide can be removed more easily than from flue gases. A numerical model has been constructed to simulate the combustion of the LCV fuel gas in the PTC. A detailed description of the test rig will be given. The first experimental results will be described and compared with simulation results obtained with the commercial Computational Fluid Dynamics code Fluent version 4.3. Finally the future work will be described.

scholarly journals Investment Behavior of Enterprises in 2019–2020

2020 ◽  
pp. 3-17
Author(s):  
S. Aukutsionek
Keyword(s):  
Capital Investment ◽  
Investment Behavior ◽  
Investment Activity ◽  
Total Capital ◽  
Total Capital Investment

The article outlines the trends of 2019 – the first half of 2020 in the field of investment behavior of enterprises. The following aspects are examined: the level of investment activity both in terms of equipment purchases and total capital investment; the rating of factors limiting capital investment; the main sources of funds for investment and principal motives to invest; the features of borrowings from banks to finance investment.

The Scale-up and Economic Evaluation of Non-Thermal Plasma Technology for a Coal Fired Power Plant Exhaust Gas Emission Control

2003 ◽  
Vol 6 (2) ◽  
Author(s):  
Kuniko Urashima ◽  
Seock Joon Kim ◽  
Jen-Shih Chang
Keyword(s):  
Economic Evaluation ◽  
Power Plant ◽  
Thermal Plasma ◽  
Annual Cost ◽  
Pilot Plant ◽  
Capital Investment ◽  
Scale Up ◽  
Total Capital ◽  
Total Capital Investment ◽  
Non Thermal Plasma

Abstract Economies of pollution control devices are critical to the decision-making in power plant emission control upgrades. The computer code (SUENTP) to predict scale up and economic evaluation of several eligible non-thermal plasma processes for power plant gaseous pollution controls was developed for electron beam, pulsed corona, and corona radical shower processes. This code was written by the spread sheet type MS Excel with visual basic for application and comprises data input procedure, scale-up (design) procedure, economic calculation procedure, and output procedures. Data obtained from pilot plant tests was used as an input data together with general data so that they might be led to the conceptual design data of commercial plants by scaleup procedure. The economic evaluation procedure consisted of the total capital investment and the total annual cost. The total capital investment was presented as the indirect annual cost in items of capital recovery. The levelized cost and the levelized bus bar cost were shown in the output table. Typical calculation was presented to evaluate the cost of three non-thermal systems based on existing pilot plant experiments. The results show that the economy of the non-thermal plasma systems are similar or less costs by compared with a conventional wet-scrubber/selective catalytic reduction combined system.

Feasibility Study of Bio-Hydrogenated Diesel (BHD) Production: A Case Study in Thailand

2014 ◽  
Vol 931-932 ◽  
pp. 162-167
Author(s):  
Kantama Angsana ◽  
Chaiwat Prapainainar ◽  
Phavanee Narataruksa ◽  
Hupinnyo Piyapong
Keyword(s):  
Cost Estimation ◽  
Capital Investment ◽  
Economic Feasibility ◽  
Unit Operations ◽  
Total Capital ◽  
Investment Cost ◽  
Total Capital Investment ◽  
Equipment Sizing ◽  
Process Simulator

It founded that crude palm oil, CPO, could be changed to Bio-hydrogenated Diesel, BHD, which has a potential to replace the petroleum-derived diesel. Therefore, techno-economic feasibility of BHD production for Thailand was studied with a capacity of 1 million liters per day (MLD) of BHD. In this work, a conceptual design of BHD process was developed by using process simulator, ASPEN Plus. Calculation of mass and energy balance, equipment sizing and cost estimation in five major unit operations were performed. The total capital investment was calculated and used for economic analysis to estimate the return on investment, price value and payback period. The results showed that total capital investment cost was 174.34 millions USD with 1 MLD of BHD, PBP was 5 years with 17.02% ROI. BHD price of 1.16 USD/L.

Sign in / Sign up

Export Citation Format

Share Document