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CCGT unit commitment model with first-principle formulation of cycling costs due to fatigue damage

ENERGY 2016年第0期113卷 227-247页

作者： Wogrin, Sonja Galbally, David Ramos, Andres Comillas Pontifical Univ Calle Alberto Aguilera 23 Madrid Spain Innomerics Calle San Juan de la Cruz 2 Pozuelo De Alarcon Spain

Combined cycle gas turbine power plants (CCGTs) play a key role in modern electric power systems due to their operational flexibility and the firmness they provide to the networks where they operate. Due in part to this flexibility and firmness, the function of CCGTs has experienced a significant evolution with the advent of intermittent renewable energy sources such as wind: CCGTs are increasingly required to rapidly vary load levels in order to counterbalance the fluctuations of renewable energy sources and satisfy overall system demand. The purpose of this paper is to develop a methodology that can be used for assessing the optimal operational strategy of a CCGT when subjected to cycling requirements. This is achieved by introducing a unit commitment formulation that takes into account useful life expenditure costs due to fatigue damage accumulation associated to cycling. The case studies presented in this paper show that neglecting fatigue cycling costs when making operational decisions generates suboptimal cost and profit outcomes for CCGT operators. Furthermore, it is shown that profitability of CCGTs is compromised in systems with very significant penetration of intermittent renewable energy sources, due to the increase in cycling costs derived from continuous load-following operation. (C) 2016 Elsevier Ltd. All rights reserved.

关键词： CCGT Combined cycle plants Cycling costs Fatigue damage unit commitment model Wind penetration

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Power-to-heat amine-based post-combustion CO2 capture system with solvent storage utilizing fluctuating electricity prices

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APPLIED ENERGY 2024年 368卷

作者： Isogai, Hirotaka Nakagaki, Takao Waseda Univ Environm Res Ctr 1011 Nishitomida Honjo Saitama 3670035 Japan

A thermal power plant employing amine-based post-combustion CO2 capture (PCC) stands as a key technology for low-carbon, stable power sources aiming to economically achieve net zero CO2 emissions in the electric power sector. However, the high cost associated with amine-based PCC has prevented its swift implementation. This study proposes a novel power-to-heat amine-based PCC system featuring solvent storage tanks. This system provides CO2 absorption during the operation of the thermal power plant and facilitates CO2 desorption through a heat pump driven by exceptionally inexpensive electricity procured during peak power generation periods from the grid. To demonstrate this concept, we evaluated the profitability of the proposed system using mathematical modelling and the calculation of the capital expenditure (CAPEX) and fixed operating expenses. The mathematical model optimizes the operational modes of the system facilities based on actual annual electricity prices. The results demonstrated that the novel PCC system decreased the average cost for energy consumption during the CO2 stripping and compression process per tonne of CO2 by approximately 30% compared with the conventional, flexible PCC system with venting. Consequently, it increased the net present value by approximately 15%. This showcases the feasibility of the power-to-heat amine-based PCC system in electricity markets prone to extreme fluctuations in electricity prices, where prices plummet during periods of surplus and escalate during peak demand. Notably, results also revealed that despite the low-capacity factor of the power plant (<30%) in such markets, retrofitting an amine-based PCC system into fully depreciated existing natural gas combined cycles yielded positive net present values even without economic incentives like credits for captured and stored CO2 or grant funding for CAPEX. This suggests potential economic sustainability of the system, even in the imminent rise of inexpensive variable

关键词： Carbon capture and storage (CCS) CESAR-1 Mixed-integer linear program (MILP) Flexible operation unit commitment model General algebraic modelling (GAMS)

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Optimal battery cycling strategies in workplaces with electric vehicle chargers, energy storage systems and renewable energy generation

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IET RENEWABLE POWER GENERATION 2022年第6期16卷 1121-1133页

作者： Toosi, Hooman Ekhteraei Merabet, Adel Al-Durra, Ahmed Swingler, Andrew St Marys Univ Div Engn Halifax NS Canada Khalifa Univ Dept EECS Adv Power & Energy Ctr Abu Dhabi U Arab Emirates Univ Prince Edward Isl Sustainable Design Engn Fac Charlottetown PE Canada

Efficient unit commitment strategy in a modern workplace facilitated with electric vehicle (EV) chargers and energy storage systems requires implementation of optimal battery cycling for both local storage system and electric vehicle batteries. In order to achieve this goal, it is necessary to address the battery health in the energy management strategies of commercial buildings. A fair battery cycling approach that could consider the interests of both parties in a workplace (including the system operator and the EV owners) requires access to detailed information on battery performance and degradation-associated costs. In this study, a detailed investigation is carried out on the optimal battery cycling in a workplace that is facilitated with an EV charging station, energy storage system and renewable energy generation. This is carried out by employment of a tailored unit commitment model that can address the battery health for EVs, individually. This study illustrates how a business owner and the employees that own electric vehicles can benefit from bidirectional battery cycling in an equitable way without compromising their financial interests in the energy market.

关键词： battery powered vehicles electric vehicles electric vehicle charging power markets secondary cells power generation dispatch power generation economics local storage system optimal battery cycling strategies battery chargers EV owners electric vehicle batteries unit commitment model unit commitment strategy electric vehicle chargers energy management strategies energy storage system bidirectional battery cycling renewable energy generation battery performance battery health energy management systems power generation scheduling energy market

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The unit commitment model with concave emissions costs: a hybrid Benders' Decomposition with nonconvex master problems

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ANNALS OF OPERATIONS RESEARCH 2013年第1期210卷 361-386页

作者： Van Dinter, Jennifer Rebennack, Steffen Kallrath, Josef Denholm, Paul Newman, Alexandra Colorado Sch Mines Div Econ & Business Golden CO 80401 USA Univ Florida Dept Astron Gainesville FL 32611 USA NREL Energy Forecasting & Modeling Grp Golden CO 80401 USA

We present a unit commitment model which determines generator schedules, associated production and storage quantities, and spinning reserve requirements. Our model minimizes fixed costs, fuel costs, shortage costs, and emissions costs. A constraint set balances the load, imposes requirements on the way in which generators and storage devices operate, and tracks reserve requirements. We capture cost functions with piecewise-linear and (concave) nonlinear constructs. We strengthen the formulation via cut addition. We then describe an underestimation approach to obtain an initial feasible solution to our model. Finally, we constitute a Benders' master problem from the scheduling variables and a subset of those variables associated with the nonlinear constructs;the subproblem contains the storage and reserve requirement quantities, and power from generators with convex (linear) emissions curves. We demonstrate that our strengthening techniques and Benders' Decomposition approach solve our mixed integer, nonlinear version of the unit commitment model more quickly than standard global optimization algorithms. We present numerical results based on a subset of the Colorado power system that provide insights regarding storage, renewable generators, and emissions.

关键词： Integer programming applications unit commitment model Power systems Benders' Decomposition Spinning reserves Mixed integer nonlinear programming Storage Renewables Convex underestimators

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The Impact of a Carbon Tax on the CO2 Emissions Reduction of Wind

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ENERGY JOURNAL 2020年第1期41卷 1-31页

作者： Chyong, Hi Kong Guo, Bowei Newbery, David Univ Cambridge EPRG Cambridge England Univ Cambridge Fac Econ Cambridge England

Energy policy aims to reduce emissions at least long-run cost while ensuring reliability. Its effecacy depends on the cost of emissions reduced. Britain introduced an additional carbon tax (the Carbon Price Support, CPS) for fuels used to generate electricity that by 2015 added 18 pound/t CO2, dramatically reducing the coal share from 41% in 2013 to 6% in 2018. Policies have both short and long-run impacts. Both need to be estimated to measure carbon savings. The paper shows how to measure the Marginal Displacement Factor (MDF, tonnes CO2/MWh) for wind. The short-rim (SR) MDF is estimated econometrically while the long-run (LR) MDF is calculated from a unit commitment model of the GB system in 2015. We examine counter-factual fuel and carbon price scenarios. The CPS lowered the SR-MDF by 7% in 2015 but raised the LR-MDF (for a 25% increase in wind capacity) by 18%. We discuss reasons for the modest differences in the SR- and LR-MDFs.

关键词： Wind marginal displacement factors carbon pricing fuel mix unit commitment model econometrics

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A unit commitment model with Demand Response for the Integration of Renewable Energies

A Unit Commitment Model with Demand Response for the Integra...

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IEEE Power and Energy Society General Meeting

作者： Yuichi IKEDA Takashi IKEGAMI Kazuto KATAOKA Kazuhiko OGIMOTO Collaborative Research Center for Energy Engineering Institute of Industrial Science University of Tokyo 4-6-1 Komaba Meguro-ku Tokyo 153-8505 JAPAN

ISBN: (纸本)9781467327275

The output of renewable energy fluctuates significantly depending on weather conditions. We develop a unit commitment model to analyze requirements of the forecast output and its error for renewable energies. Our model obtains the time series for the operational state of thermal power plants that would maximize the profits of an electric power utility by taking into account both the forecast error for renewable energies and the demand response of consumers. We consider a power system consisting of thermal power plants, photovoltaic systems (PV), and wind farms. First we analyze the effect of the forecast error on the operation cost and reserves. We confirm that the operation cost was increased with the forecast error. Then the effect of a sudden decrease in wind power is analyzed. More thermal power plants need to be operated to generate power to absorb this sudden decrease in wind power. The increase in the number of operating thermal power plants within a short period does not affect the total operation cost significantly. Finally, the effects of the demand response in the case of a sudden decrease in wind power are analyzed. We confirm that the number of operating thermal power plants is reduced by the demand response. A power utility has to continue to use thermal power plants for ensuring the supply-demand balance;some of these plants can be decommissioned after installing a large number of wind farms or PV systems, if the demand response is applied with an appropriate price structure.

关键词： unit commitment model Demand Response Demand-Responsive Renewable energy Thermoelectric Power Plants Wind farms unit commitment electricity company Wind energy Power Plants

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Flexibility evaluation of integrating solar power into the Nigerian electricity grid

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IET RENEWABLE POWER GENERATION 2017年第2期11卷 239-246页

作者： Eni, Richardson O. Akinbami, John-Felix K. Obafemi Awolowo Univ African Inst Sci Policy & Innovat Fac Technol Ife Nigeria Obafemi Awolowo Univ Energy Management & Technol Unit Ctr Energy Res & Dev Ife Nigeria

The study evaluated the capability of current thermal generation to back-up variation generation from solar energy penetration into the Nigerian power grid from a system operation perspective using security constraint unit commitment model. This provides an empirical evidence of the impacts that can tip the balance towards a sustainable future low carbon electricity mix. Through 10 and 20% solar energy penetration scenarios, greenhouse reduction of 1975.70 and 3590.03 lb/day, respectively, can be achieved. However, daily peak-valley net demand difference to be supplied by the thermal plants will increase from 702.5 to 857.5 and 1607.5 MW, numbers of daily start-up will increase from 23 to 30 and 25, daily system spinning reserve will increase from 723 to 757 and 815 MW and daily idle hours of the thermal plants will increase from 52 to 71 and 72 h, in a 10 and 20% solar energy integrated system, respectively. The daily operational revenue of the thermal plants will also reduce by 5.5 and 7.9% in a 10 and 20% solar energy integrated system, respectively. These are useful data in developing policy framework for the future electricity market as the country diversify her energy source and mitigate greenhouse effect.

关键词： power grids thermal power stations power generation dispatch power generation scheduling air pollution control power markets solar power stations flexibility evaluation solar power Nigerian electricity grid thermal generation solar energy penetration power grid security constraint unit commitment model low carbon electricity mix greenhouse reduction peak-valley net demand thermal plants solar energy integrated system electricity market greenhouse effect mitigation power 702.5 MW power 857.5 MW power 1607.5 MW power 723 MW to 757 MW power 815 MW

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Value of power plant flexibility in power systems with high shares of variable renewables: A scenario outlook for Germany 2035

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ENERGY 2017年 137卷 823-833页

作者： Kopiske, Jakob Spieker, Sebastian Tsatsaronis, George Tech Univ Berlin Inst Energy Engn Marchstr 18 D-10587 Berlin Germany

As part of the German transition towards a low-carbon economy, renewable energies are set to account for more than half of the gross electricity consumption by 2035, resulting in a rising flexibility demand. Flexibility is required to balance fluctuations in the residual load. In addition, uncertainties in the wind and solar power generation cause an increased demand for control reserve. A unit commitment model of the German power system is used to analyze the value of power plant flexibility in systems with high shares of variable renewables. To investigate the value of power plant flexibility, the additional revenue that can be generated by flexibility improvements is calculated. The results indicate, that power plant flexibility has a small positive impact on the power plant's contribution margin in 2014. A future power system configuration according to the German Grid Development Plan would provide sufficient flexibility to integrate high shares of renewables without power plant flexibility being very valuable. However, integrating variable renewables into a system relying on coal-fired and nuclear power stations results in power plants being able to significantly increase their revenue with improved flexibility. Under these circumstances, power plant flexibility has a considerable value. (C) 2017 Elsevier Ltd. All rights reserved.

关键词： Power plant flexibility unit commitment model Electricity market Control reserve Renewable energies Equilibrium pricing Non-convexities

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Flexibilization of steam power plants as partners for renewable energy systems 19

Flexibilization of steam power plants as partners for renewa...

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19th Power Systems Computation Conference (PSCC)

作者： Richter, M. Moellenbruck, F. Obermueller, F. Knaut, A. Weiser, F. Lens, H. Lehmann, D. Univ Duisburg Essen Chair Environm Proc Engn & Plant Design D-45141 Essen Germany Univ Cologne Inst Energy Econ D-50827 Cologne Germany STEAG Energy Serv GmbH D-45128 Essen Germany

ISBN: (纸本)9788894105124

Increasing the flexibility of conventional power plants is one key challenge for the massive integration of highly volatile renewable energy resources into the German and European power system. Flexible power plants ensure the security of supply by compensating fluctuations in the electrical grid caused by intermittent renewable energy production from wind and sun. In this paper, the future development of the German electricity market is predicted and evaluated in terms of the future flexibility demand of coal-fired power plants based on simulation studies for four distinct years. As the flexibility measures for coal-fired power plants generally use inherent capabilities of the existing power plant systems, they are usually restricted by limiting factors. Here, the limiting factors for reducing the minimum load and increasing load change rates are discussed and potential measures to mitigate their influence are presented. An alternative way to increase the flexibility lies in properly integrating thermal energy storages. This integration is presented and evaluated using a dynamic power plant model in EBSILON (R) Professional. Simulations show that by integrating this storage concept the electrical minimum load can be reduced while simultaneously increasing the load change rate.

关键词： Dynamic power plant simulation Electricity market modeling Power plant flexibility Thermal energy storage unit commitment model

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Active participation of wind power in operating reserves

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IET RENEWABLE POWER GENERATION 2015年第6期9卷 566-575页

作者： De Vos, Kristof Driesen, Johan KU Leuven EnergyVille Dept Elect Engn Div ELECTA B-3001 Heverlee Belgium

The increasing share of variable renewable energy sources for electricity increases the operating reserve requirements of power systems. This contribution studies the techno-economic feasibility of procuring reserve capacity as an ancillary service from wind power producers. Research and demonstration have shown that wind power is able to meet the technical requirements of providing these balancing services. This study shows how acceptable availability levels can be achieved when using probabilistic forecast models in combination with day-ahead procurement. The participation of wind power is analysed with a unit commitment model in order to determine the impact on generation system scheduling, as well as the electricity generation costs. Simulations show how wind power becomes a potential provider of downward reserve capacity when facing high reserve capacity requirements during periods with low demand and high renewable generation. In contrast, its participation in the upward reserve capacity remains limited, explained by the high opportunity cost.

关键词： wind power plants power generation economics power generation scheduling probability economic forecasting active wind power participation variable renewable energy sources operating reserve requirements power systems techno-economic feasibility reserve capacity procurement ancillary service balancing services availability levels probabilistic forecast models day-ahead procurement unit commitment model generation system scheduling electricity generation costs

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