Stochastic frequency-security constrained energy and reserve management of an inverter interfaced islanded microgrid considering demand response programs

Rezaei, Navid; Kalantar, Mohsen

doi:10.1016/j.ijepes.2015.01.023

Cited by 84 publications

(62 citation statements)

References 43 publications

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“…For example, a stochastic multi-objective framework is proposed in [19] for joint energy and reserve scheduling in day-ahead, however this reference does not consider AC network, voltage security, load and wind power uncertainties. In [20], a security-constrained energy management is presented with considering the steady-state frequency response of the MG. Moreover, the authors investigate the effect of DR participants on frequency security as a linearized ancillary service of DR programs.…”

Section: Ns T I R mentioning

confidence: 99%

“…Also, five RES plants including three WTs and two PVs are connected in different buses. The data associated with the installed generation units are given in Table 2, [20]. …”

Section: Objective Functionmentioning

confidence: 99%

“…5 [20]. It is assumed that the PV plants operate at unity power factor while the WT units operate at 0.95 legging power factor.…”

Section: The Single Line Diagram Of a Typical Low-voltage Mg Involvinmentioning

confidence: 99%

“…The costs of demand-side reserves are 2 and 1.7 cent/kW for up and down spinning reserves, respectively. Besides, the generation costs of WT and PV systems are 10.63 and 54.84 cent/kWh, respectively, and the value of lost load (VOLL) is 1000 cent/kWh [20]. Moreover, it is assumed that the prices for buying and selling deviation power from unit i, WT and PV are equal to their energy bids in day-ahead market.…”

Section: The Single Line Diagram Of a Typical Low-voltage Mg Involvinmentioning

confidence: 99%

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Optimal scheduling of distributed energy resources and responsive loads in islanded microgrids considering voltage and frequency security constraints

Vahedipour‐Dahraie

Najafi

Anvari‐Moghaddam

et al. 2018

Journal of Renewable and Sustainable Energy

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Low inertia of distributed energy resources (DERs), high penetration levels of renewable energy sources (RESs) and load demand variations put the islanded microgrids (MGs) security at risk of instability. This paper proposes a twostage stochastic model for coordination of DERs and responsive loads in islanded MGs with regard to voltage and frequency security constraints. Based on the proposed model, scheduling of the controllable units in both supply and demand sides is done in a way not only to maximize the expected profit of MG operator (MGO), but also to minimize the energy payments of customers under the premise of security and stability of MG. An AC optimal power flow (AC-OPF) procedure is also used to study operating condition of the system under uncertainties and to guarantee acceptable nodal voltages and system frequency during different scenarios. The proposed stochastic optimization model is then applied to a typical autonomous MG and its effectiveness is demonstrated through different scenarios under uncertainties in load consumption and renewable energy resources (RESs) productions. Simulation results demonstrate that customers' participation in DR programs have significant effect on the system's performance in terms of voltage and frequency stability. Moreover, optimal coordination of DERs and responsive loads can increase the expected profit of MGO significantly. The effectiveness of the proposed scheduling approach is verified on an islanded MG test system over a 24-h period.Index Terms-Demand response (DR), microgrid (MG), distributed energy resource (DER), voltage and frequency security, renewable energy sources (RESs). DR t j D BIncome of group j of customer at period t after implementing DR programs. ,t j BIncome of group j of customer at period t when the demand is at nominal value. Energy bid submitted by wind unit w (PV v) in period t (cents/kWh).Bid of the up (down)-spinning reserve submitted by DG i in period t (cents/kWh).Bid of the non-spinning reserve submitted by DG i in period t (cents/kWh).Bid of the up (down)-spinning reserve submitted by load j in period t (cents/kWh).Demand of load j in period t (and scenario s) (kW).Demand of load group j after implementing DR programs in period t (kW).Self-elasticity (Cross-elasticity) of load group j. LFMaximum power flow from node n to r (kW). 2I. Introduction Recently, microgrid (MG) idea has been introduced to transform the conventional power systems to a more reliable, economic and environmentally friendly system. The diversified load consumption pattern and availability of power from green distributed energy resources (DERs) cause supply-demand mismatch in MGs. Optimal operation of MGs both technically and economically mainly relies on the coordination between different components including DERs, energy storage systems (ESSs), and responsive loads [1]- [2]. In grid-connected MGs, normally the economic operation is the main objective as there is a stiff-grid on upstream to support the system frequency and voltage at the point of ...

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Section: Ns T I R mentioning

confidence: 99%

“…Also, five RES plants including three WTs and two PVs are connected in different buses. The data associated with the installed generation units are given in Table 2, [20]. …”

Section: Objective Functionmentioning

confidence: 99%

“…5 [20]. It is assumed that the PV plants operate at unity power factor while the WT units operate at 0.95 legging power factor.…”

Section: The Single Line Diagram Of a Typical Low-voltage Mg Involvinmentioning

confidence: 99%

Section: The Single Line Diagram Of a Typical Low-voltage Mg Involvinmentioning

confidence: 99%

See 2 more Smart Citations

Optimal scheduling of distributed energy resources and responsive loads in islanded microgrids considering voltage and frequency security constraints

Vahedipour‐Dahraie

Najafi

Anvari‐Moghaddam

et al. 2018

Journal of Renewable and Sustainable Energy

View full text Add to dashboard Cite

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“…Their output power scenarios are reduced by applying a k-means algorithm as shown in Figure 2. Technical specifications of the simulated MG components are given in Table 1 [34]. Moreover, the hourly load profile of the MG is illustrated in Figure 3 and is supposed to be divided into three different periods, namely valley period (00:00-5:00), off-peak periods (5:00-10:00, 16:00-19:00 and 22:00-24:00) and peak periods (11:00-15:00 and 20:00-22:00).…”

Section: Test Casementioning

confidence: 99%

Study of the Effect of Time-Based Rate Demand Response Programs on Stochastic Day-Ahead Energy and Reserve Scheduling in Islanded Residential Microgrids

et al. 2017

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Abstract:In recent deregulated power systems, demand response (DR) has become one of the most cost-effective and efficient solutions for smoothing the load profile when the system is under stress. By participating in DR programs, customers are able to change their energy consumption habits in response to energy price changes and get incentives in return. In this paper, we study the effect of various time-based rate (TBR) programs on the stochastic day-ahead energy and reserve scheduling in residential islanded microgrids (MGs). An effective approach is presented to schedule both energy and reserve in presence of renewable energy resources (RESs) and electric vehicles (EVs). An economic model of responsive load is also proposed on the basis of elasticity factor to model the behavior of customers participating in various DR programs. A two-stage stochastic programming model is developed accordingly to minimize the expected cost of MG under different TBR programs. To verify the effectiveness and applicability of the proposed approach, a number of simulations are performed under different scenarios using real data; and the impact of TBR-DR actions on energy and reserve scheduling are studied and compared subsequently.

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Security-constrained unit commitment in AC microgrids considering stochastic price-based demand response and renewable generation

Vahedipour-Dahraei

Najafi

Anvari‐Moghaddam

2018

Int Trans Electr Energ Syst

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Summary In this paper, a stochastic model for scheduling of AC security‐constrained unit commitment associated with demand response (DR) actions is developed in an islanded residential microgrid. The proposed model maximizes the expected profit of microgrid operator and minimizes the total customers' payments for electricity consumption under load and renewable energy sources uncertainties. In this regard, a stochastic dispatch model for responsive load is developed in order to investigate the effect of price‐based DR programs in a microgrid environment. In this scheme, customers are able to participate in real‐time price program with shifting and curtailing their responsive loads. A multi‐segment AC‐optimal power flow, which allows the voltage and reactive power to be considered directly, is also used to study the effects of DR participation on microgrid operation. The proposed AC security‐constrained unit commitment and DR scheduling problem is modeled as a mixed‐integer programming problem and is solved using the CPLEX solver in the general algebraic modeling system.

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Stochastic frequency-security constrained energy and reserve management of an inverter interfaced islanded microgrid considering demand response programs

Cited by 84 publications

References 43 publications

Optimal scheduling of distributed energy resources and responsive loads in islanded microgrids considering voltage and frequency security constraints

Optimal scheduling of distributed energy resources and responsive loads in islanded microgrids considering voltage and frequency security constraints

Study of the Effect of Time-Based Rate Demand Response Programs on Stochastic Day-Ahead Energy and Reserve Scheduling in Islanded Residential Microgrids

Security-constrained unit commitment in AC microgrids considering stochastic price-based demand response and renewable generation

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