Optimization of the Managing Strategy of a Cogenerative Power Park in a Liberalized Market

2004 ◽  
Author(s):  
Paolo Silva ◽  
Stefano Campanari ◽  
Ennio Macchi ◽  
Stefano Delfino
Keyword(s):  
Peak Load ◽  
District Heating ◽  
Operating Mode ◽  
Combined Cycle ◽  
Complex Case ◽  
Time Variability ◽  
Optimization Strategy ◽  
Power Stations ◽  
Managing Strategy ◽  
Prime Movers

The paper addresses the optimization of the managing strategy of a cogenerative power park in a liberalized market characterized by great time variability of the electricity sale price. Besides electric tariffs and marginal costs, a variety of other factors affects the selection of operating mode of the prime movers, such as environmental conditions, O&M costs, range of plant output regulation capability and performance deterioration of the components. The optimum plant operating schedule is found with reference to a tariff scenario where the base-load, mid-term and peak-load electricity costs are set by economical competition among a variety of power stations. The first part of the paper focuses on the case of a single cogenerative combined cycle, generating heat and electricity for an industrial load. The paper then deals with the extension of the optimization strategy to the more complex case of a combination of various prime movers (including combined cycle, combustion turbines and reciprocating gensets), all feeding the same district heating network. The results indicate the utmost importance of a correct management of the power stations for the achievement of best energy ad economic results.

Optimization of Operating Conditions and Compressor Cleaning Time Intervals of Combined Cycles in a Liberalized Market

2003 ◽  
Author(s):  
Paolo Silva ◽  
Stefano Campanari ◽  
Ennio Macchi
Keyword(s):  
Power Plant ◽  
Power Plants ◽  
Oil And Gas ◽  
Combined Cycle ◽  
Operating Conditions ◽  
Time Variability ◽  
Primary Role ◽  
Steam Power ◽  
Combined Cycle Power Plant ◽  
Power Stations

The paper addresses the optimization of the managing strategy of a combined cycle power plant in a liberalized market characterized by great time variability of the electricity sale price. Besides electric tariffs, a variety of other factors affect the selection of the plant operating mode, such as environmental conditions, O&M costs, range of plant output regulation capability, performance deterioration of the components and compressor fouling rate. All calculations refer to a real combined cycle power plant owned by an Italian utility, for which are available detailed performance data, in “new and clean” conditions as well as in real operation. The optimum plant operating schedule is found with reference to three different tariff scenarios: (i) the present Italian situation, characterized by the primary role of oil and gas fired steam power stations, (ii) the Italian situation foreseen after the massive repowering program of existing steam power plants is completed, and (iii) a situation where the base-load electricity is generated by coal-fired power stations. The comparison indicates the utmost importance of the reference tariff scenario on the actual energy ad economic budget of the power station.

scholarly journals The Prospect of Solar Energy in the Development of Power Stations in the State of Kuwait

2013 ◽  
Vol 2013 ◽  
pp. 1-6 ◽  
Author(s):  
Mohammad Ramadhan ◽  
Abdulhameed Hussain ◽  
Dina Behbehani
Keyword(s):  
Power Generation ◽  
Solar Energy ◽  
Gas Turbine ◽  
Peak Load ◽  
Production Capacity ◽  
Combined Cycle ◽  
Economic Feasibility ◽  
Fuel Oil ◽  
Power Stations ◽  
The State Of Kuwait

Over the years, the production capacity for power generation has not been able to keep pace with the surge in electricity demand in the oil-rich State of Kuwait. To expand its power generation capacity, Kuwait's strategic energy plans focus on constructing gas turbine and fuel oil stations. This paper aimed to evaluate the prospect of photovoltaic solar energy (PV) in generating electricity as an alternative to decrease dependency on combined cycle gas turbine (CCGT) power stations. It applies the LCOE framework to evaluate the economic feasibility of installing a 100 MW PV and CCGT power stations in Kuwait. The results indicate that under the assumption of 5% interest rate, the estimated LCOE of PV station ($0.19/kWh) is unfeasible in comparison to the generation cost of gas turbine station ($0.11/kWh). However, the analysis has emphasized that evaluation of future electricity generation plans must not be limited to the LCOE criteria and should incorporate the following factors: the effect of natural gas supply constraints on the production of gas turbine plants, the environmental concerns of CO2emissions, the peak load demand, and the domestic energy balance mix. The paper concludes that once these factors are addressed properly, the prospect of PV power stations becomes relatively feasible.

An Air-Brayton Nuclear-Hydrogen Combined-Cycle Peak- and Base-Load Electric Plant

2007 ◽  
Author(s):  
Charles Forsberg
Keyword(s):  
High Temperature ◽  
Power Output ◽  
Nuclear Reactor ◽  
Peak Load ◽  
Combined Cycle ◽  
Operating Conditions ◽  
Electricity Production ◽  
Spinning Reserve ◽  
High Temperature Reactor ◽  
Base Load

A combined-cycle power plant is proposed that uses heat from a high-temperature nuclear reactor and hydrogen produced by the high-temperature reactor to meet base-load and peak-load electrical demands. For base-load electricity production, air is compressed; flows through a heat exchanger, where it is heated to between 700 and 900°C; and exits through a high-temperature gas turbine to produce electricity. The heat, via an intermediate heat-transport loop, is provided by a high-temperature reactor. The hot exhaust from the Brayton-cycle turbine is then fed to a heat recovery steam generator that provides steam to a steam turbine for added electrical power production. To meet peak electricity demand, after nuclear heating of the compressed air, hydrogen is injected into the combustion chamber, combusts, and heats the air to 1300°C—the operating conditions for a standard natural-gas-fired combined-cycle plant. This process increases the plant efficiency and power output. Hydrogen is produced at night by electrolysis or other methods using energy from the nuclear reactor and is stored until needed. Therefore, the electricity output to the electric grid can vary from zero (i.e., when hydrogen is being produced) to the maximum peak power while the nuclear reactor operates at constant load. Because nuclear heat raises air temperatures above the auto-ignition temperatures of the hydrogen and powers the air compressor, the power output can be varied rapidly (compared with the capabilities of fossil-fired turbines) to meet spinning reserve requirements and stabilize the grid.

Gas Turbine Control System Integration for Royal Caribbean Millennium Class Cruise Liner

2000 ◽  
Author(s):  
David J. Olsheski ◽  
William W. Schulke
Keyword(s):  
Control System ◽  
Steam Turbine ◽  
Gas Turbine ◽  
Waste Heat ◽  
Combined Cycle ◽  
Direct Drive ◽  
Dynamic Features ◽  
Turbine Generator ◽  
Marine Propulsion ◽  
Prime Movers

Traditionally commercial marine propulsion needs have been met with direct drive reciprocating prime movers. In order to increase efficiency, simplify installation and maintenance accessibility, and increase cargo / passenger capacity; indirect electric drive gas and steam turbine combined cycle prime movers are being introduced to marine propulsion systems. One such application is the Royal Caribbean Cruise Line (RCCL) Millennium Class ship. This commercial vessel has two aero-derivative gas turbine generator sets with a single waste heat recovery steam turbine generator set. Each is controlled by independent microprocessor based digital control systems. This paper addresses only the gas turbine control system architecture and the unique safety and dynamic features that are integrated into the control system for this application.

Rosenhain Centenary Conference - 1. Engineering requirements 1.6 Gas turbine requirements Discussion

1976 ◽  
Vol 282 (1307) ◽  
pp. 123-130
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
High Strain ◽  
Peak Load ◽  
Great Majority ◽  
Growth Monitoring ◽  
Fuel Quality ◽  
High Sodium ◽  
Power Stations ◽  
Operational Life

The C.E.G.B. interest in gas turbines has developed steadily during the past decade from auxiliary service functions in large fossil-fuelled power stations to small power stations, entirely of gas turbine plant, whose principal purpose is to meet peak load demands. Here the ability of the gas turbine to be started up very rapidly is an important attribute. The great majority of these gas turbine units have been derived from the use of established aero engines, such as the Avon and Olympus, as gas generators to drive a power turbine. These units are subject to planned maintenance after, at the most, 2000 h of operation when burning distillate fuel. There have been instances of blade corrosion problems due to sulphidation attack and related high sodium levels in the fuel; the solution to this problem has been to control the fuel quality. Two prototype industrial gas turbines, each of ca. 55 MW output, are due to be commissioned at one of the Board’s power stations in the near future. Here the aimed-for operational life before undertaking planned maintenance will be ca. 20000 h. This places greater emphasis on the need to appreciate any time-dependent process affecting engineering performance. From a materials standpoint these are corrosion resistance, thermal and high strain fatigue and creeprupture. Specific problems under study in blade materials are the consequences of corrosion-resistant coatings upon the mechanical properties and the limits of acceptability of defects. The latter involves crack growth monitoring under conditions of creep, high strain and high cycle fatigue. As the future emphasis should be directed towards gaining a better understanding of material behaviour in the projected engineering situations the physical metallurgist has to think beyond the metals themselves and consider, for example, the interactions that occur between metals and coatings.

Conceptual Design for Medium Size Combined Cycle Plants Improved by Recent Research and Innovation

2000 ◽  
Author(s):  
H. Jericha ◽  
F. Neumayer
Keyword(s):  
Conceptual Design ◽  
Gas Turbines ◽  
Cooling System ◽  
Economic Value ◽  
District Heating ◽  
Combined Cycle ◽  
Medium Size ◽  
Research And Innovation ◽  
Combined Cycle Plant ◽  
Reheat Steam

A conceptual design study for a 120 MW combined cycle plant is presented here. Values of 60% thermal efficiency are at present the realm of very large gas turbines of most advanced design with power outputs of 300 to 500 MW. For industry and district heating plants it would be of most economic value to achieve similar thermal efficiencies in medium size gas turbines and combined cycle plants as they are being installed in Central European cogeneration and district heating plants. The authors propose by concerted application of recent research results to achieve this goal for medium size combined cycle plants. Design measures incorporated are transonic turbine stages, an innovative cooling system and a 600 degree reheat steam turbine.

300 MW Combined-Cycle Plant With Integrated Coal Gasification

1984 ◽  
Author(s):  
Rolf H. Kehlhofer
Keyword(s):  
Power Generation ◽  
Power Plant ◽  
Gas Turbines ◽  
Power Plants ◽  
Coal Gasification ◽  
District Heating ◽  
Combined Cycle ◽  
Liquid Fuels ◽  
Combined Cycle Plant ◽  
The Individual

In the past 15 years the combined-cycle (gas/steam turbine) power plant has come into its own in the power generation market. Today, approximately 30 000 MW of power are already installed or being built as combined-cycle units. Combined-cycle plants are therefore a proven technology, showing not only impressive thermal efficiency ratings of up to 50 percent in theory, but also proving them in practice and everyday operation (1) (2). Combined-cycle installations can be used for many purposes. They range from power plants for power generation only, to cogeneration plants for district heating or combined cycles with maximum additional firing (3). The main obstacle to further expansion of the combined cycle principle is its lack of fuel flexibility. To this day, gas turbines are still limited to gaseous or liquid fuels. This paper shows a viable way to add a cheap solid fuel, coal, to the list. The plant system in question is a 2 × 150 MW combined-cycle plant of BBC Brown Boveri with integrated coal gasification plant of British Gas/Lurgi. The main point of interest is that all the individual components of the power plant described in this paper have proven their worth commercially. It is therefore not a pilot plant but a viable commercial proposition.

The Extension of Gas Turbine Power Plants to Combined Cycle Power Stations

1986 ◽  
Author(s):  
Wolfgang Schemenau ◽  
Ulrich Häuser
Keyword(s):  
Developing Countries ◽  
Gas Turbine ◽  
Power Plants ◽  
Electricity Consumption ◽  
Combined Cycle ◽  
Ambient Conditions ◽  
Continuous Growth ◽  
Clean Fuel ◽  
Industrial Countries ◽  
Power Stations

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.

Gainesville Regional Utilities Kelly Plant Asset Management With Cycling Operation

2015 ◽  
Author(s):  
Douglas Hilleman ◽  
John M. Lindsay ◽  
Tim Hinson
Keyword(s):  
Asset Management ◽  
Distribution System ◽  
Peak Load ◽  
Combined Cycle ◽  
Thermal Systems ◽  
Fuel Storage ◽  
Pumping Equipment ◽  
Business District ◽  
Operational Impacts ◽  
Transmission And Distribution

Gainesville Regional Utilities (GRU) is a fully vertically-integrated utility with electric power generation, transmission, and distribution system owned by the City of Gainesville, FL. We have two primary generating plant sites: Deerhaven with two conventional coal-fired steam units (DH1 and DH2) and John R. Kelly (JCC1) combined-cycle Unit 1. Kelly Station (the focus of this study) is located in southeast Gainesville near the downtown business district. It has one - 120 MW combined-cycle unit (JCC1) in 1 × 1 configuration, consisting of: one GE Frame 7E combustion turbine (dual fuel), one Applied Thermal Systems two pressure HRSG, one 50-year old Westinghouse steam turbine unit with cooling tower, fuel storage, pumping equipment, transmission, and distribution equipment. In 2013, GRU with a seasonal peak load of approximately 500 MWs was to start receiving the output of a new 100 MW bio-fuel plant under a purchase power agreement. It was apparent that the operation of the GRU units would drastically change. It was predicted by GRU that DH2 a 255 MW coal unit would move to a cycling duty unit and the Kelly combined-cycle unit would be relegated to “peaking” operation. To better understand and predict future operational impacts, GRU contracted with Intertek AIM (APTECH) to conduct a Cost of Cycling study. This paper is our presentation of the results of the study and the changes that were indicated by the cycling analysis to manage the GRU system at the lowest cost and to incorporate the new modes of cycling operation. The expected modes of operation based on the results of the study were reversed to use the lowest cost unit for frequent cycling of JCC1 and changed the previously base loaded coal unit DH2 into a seasonal unit with long seasonal shut downs. This paper further shows the actions implemented by GRU at Kelly station to improve the cycling response and reduce the damage impact of each cycle by managing the startup ramp rates of the limiting equipment. The plant had limited budget for capital improvements and focused principally on managing the cost by modifying the startup procedures using real time operating data. Our conclusion was that by following the report recommendations, a new “Start Model” produced repeatable and acceptable results that minimized possible damage to the unit while meeting the need to use the renewable energy and support the customer by providing power at the lowest cost. The paper will demonstrate the improvement areas, the actual changes, and the results of those changes to the cycling data and the savings due to reduced damage.

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