Stochastic Optimization of Sub-Hourly Economic Dispatch With Wind Energy

Gangammanavar, Harsha; Sen, Suvrajeet; Zavala, Ví­ctor M.

doi:10.1109/tpwrs.2015.2410301

Cited by 86 publications

(40 citation statements)

References 24 publications

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“…The SO-based approach introduced as early as Dantzig [7] relies on pre-sampling discrete scenarios of the uncertainty realizations [8,9] via presumed probability distribution functions (PDFs) of uncertainty parameters and tries to compute a solution which optimizes the expected value of the objective function. Representative researches include stochastic security-constrained unit commitment (SCUC) [8], [10,11], stochastic ED [12,13], DR dispatch [14,15], stochastic optimal power flow (OPF) [16,17], and stochastic electric vehicle (EV) charging [18,19]. But the SO-based approach still has practical limitations in its application to large scale power systems.…”

Section: Introductionmentioning

confidence: 99%

RETRACTED: Active robust optimization for wind integrated power system economic dispatch considering hourly demand response

Wang

Jiang

2016

Renewable Energy

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a b s t r a c tDue to dramatically increased uncertainties caused by wind power (WP) integration and price responsive demand, economic dispatch (ED) in a day-ahead market faces new challenges. With the involvement of price responsive demand response (DR), independent system operator (ISO) has to adapt to the changes of both nodal prices and loads under different WP conditions. Moreover, here the changeable nodal prices are determined by both power generation and load not using a simple deterministic mathematical function. The robustness of dispatch strategies can be enhanced through proper demand side management. Motivated by these, we propose a novel active robust optimization dispatch (AROD) model in this paper. The proposed model amalgamates robust optimization (RO) with dynamic optimization (DO) to reveal the effects of price responsive DR, while considering all possible WP conditions. We present extensive numerical case studies on the modified IEEE 30-bus system and IEEE 118-bus system. Computational results demonstrate the effectiveness of the proposed AROD model for the secure and economic operation of the power system under various uncertainties in a day-ahead market.

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Section: Introductionmentioning

confidence: 99%

RETRACTED: Active robust optimization for wind integrated power system economic dispatch considering hourly demand response

Wang

Jiang

2016

Renewable Energy

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“…Lastly, we evaluated the computation time required to solve the optimization problem, which is quite important because short-term unit commitment (STUC) is conducted in the hours prior to real-time operation in today's power systems [24]. The computational times of the proposed method and the conventional one are shown in Table 6.…”

Section: Numerical Resultsmentioning

confidence: 99%

“…The constraints, Equations (23)- (25), are related to the spinning reserve. The spinning reserve, which can be provided by generating units, are constrained by their maximum available power, Equation (23), and by their ramping capability, Equation (24). The ramp up/down limit for the generating units are expressed as Equations (26) and (27) A more detailed description of the equations can be found in [4,18].…”

Section: Constraintsmentioning

confidence: 99%

Considering Maintenance Cost in Unit Commitment Problems

Park

et al. 2017

Energies

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Electric power systems worldwide are receiving an increasing volume of wind power generation (WPG) because of environmental concerns and cost declines associated with technological innovation. To manage the uncertainty of WPG, a system operator must commit sufficient conventional generators to provide an appropriate reserve. At times, frequent start and stop operations are applied to certain generators, which incurs maintenance costs associated with thermal-mechanical fatigue. In this paper, we suggest a comprehensive approach to unit commitment (UC) that considers maintenance cost: the parameters of equivalent start (ES) and equivalent base load hours (EBHs) are adopted in the UC problem to determine optimal generation scheduling. A new formulation for the maintenance cost that can be readily combined with an existing mixed integer linear programming algorithm is presented. The effectiveness of the proposed UC method is verified through simulations based on an IEEE 118-bus test system. The simulation results show that considering maintenance cost in the UC problem effectively restricts frequent start and stop operation scheduling. Furthermore, the operating cost is reduced, the required reserve level is maintained, and the computational time is comparable with that of the conventional UC method.

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“…The state of the art in renewable energy integration often employs hourly time resolution for day-ahead and real-time operations [32]- [35]. Recent work by Deane et al [36] and Gangammanavar et al [37] underscores the importance of sub-hourly time resolution in accurately estimating the costs of integrating renewable energy. Bakirtzis et al [38] propose a receding horizon model with 5-minute resolution for simulating real-time operation under large-scale renewable energy integration.…”

Section: A Literature Reviewmentioning

confidence: 99%

Renewable Energy Integration in Zonal Markets

Aravena

Papavasiliou

2016

IEEE Trans. Power Syst.

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In this paper we investigate the impact of zonal network management in the operation of power systems with significant levels of renewable energy integration. Our study is inspired by the current state of the European energy market, and we focus on a case study of the Central Western European (CWE) system. First, we present a hierarchy of models that account for unit commitment, the separation of energy and reserves, and the simplified representation of transmission constraints in a zonal market, in order to examine the impact of these factors on efficiency in a regime of large-scale renewable energy integration. Second, we simulate operations of the CWE system under the zonal market design using a detailed instance that consists of 656 thermal generators, 679 nodes and 1073 lines, with multiarea renewable energy production and 15-minute time resolution. Zonal market operations are compared against deterministic and stochastic unit commitment using high performance computing in order to tackle the scale of the resulting models. We find that market design can have an influence on cost efficiency which far exceeds the benefits of stochastic unit commitment relative to deterministic unit commitment. We conduct a detailed analysis of the numerical results in order to explain the relative performance of the different models.

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Stochastic Optimization of Sub-Hourly Economic Dispatch With Wind Energy

Cited by 86 publications

References 24 publications

RETRACTED: Active robust optimization for wind integrated power system economic dispatch considering hourly demand response

RETRACTED: Active robust optimization for wind integrated power system economic dispatch considering hourly demand response

Considering Maintenance Cost in Unit Commitment Problems

Renewable Energy Integration in Zonal Markets

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