Influence of Inverter-Interfaced Renewable Energy Generators on Directional Relay and an Improved Scheme

Jia, Ke; Yang, Zhe; Fang, Yu; Bi, Tianshu; Sumner, Mark

doi:10.1109/tpel.2019.2904715

Cited by 113 publications

(49 citation statements)

References 31 publications

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“…(13), which minimizes the expected total operation cost of SDGs and the expected received energy cost from the upstream network 19 . Constraints (14)- (17) are correspond to the power flow equations, which represent the active and reactive power balance in network buses, and active and reactive power flowing through distribution lines, respectively 18,20 . In addition, the technical constraint of the distribution network including line and substation capacity limits and bus voltage limitations are expressed in Eqs.…”

Section: Proposed Protection Coordination Mechanismmentioning

confidence: 99%

“…Finally, Ref 17 examined the effects of Inverter-based DGs on the protection coordination of DOCRs. Based on the obtained results of it, these types of DGs are able to quickly interrupt their injected fault current into the network, so Inverter-based DGs don't have the same negative effects as SDGs on the protection coordination of distribution network.…”

Section: Introductionmentioning

confidence: 99%

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Security-Constrained Optimal Protection Coordination for Dual-Setting Digital Directional Overcurrent Relays in the Distribution Network Including Non-Renewable/Renewable Synchronous Distributed Generation

Pirouzi¹,

Shahi²,

Zadeh³

et al. 2021

Preprint

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In this paper, the security-constrained optimal protection coordination (SCOPC) is introduced for dual setting digital directional overcurrent relay (DDOCR) in distribution network, which including renewable and non-renewable synchronous distributed generation (SDG). The SCOPC minimizes the total operation time of DDOCRs in primary and backup protection operating to achieve a fast protection coordination. Also, to improve the flexibility in DDOCRs setting, the allowable limits of A and B coefficients, pickup current (PC) and time dial setting (TDS) in both reverse and forward directions are considered as constraints. Another constraint is the Coordination Time interval (CTI). To consideration of the mentioned scheme security, the SCOPC mechanism considered the unavailability of DDOCRs due to their failure, so the stochastic method is used to modelling of this parameter. To calculate the fault current, network variables are proportional to the daily stochastic operation results of distribution network. Moreover, the proposed problem is implemented on the standard distribution networks, and then the optimal solution is obtained with hybrid algorithm of grey wolf optimization (GWO) and training and learning optimization (TLBO). The numerical results illustrate that the proposed algorithm is able to achieve a reliable and fast protection coordination that has a low standard deviation.

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Section: Proposed Protection Coordination Mechanismmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Security-Constrained Optimal Protection Coordination for Dual-Setting Digital Directional Overcurrent Relays in the Distribution Network Including Non-Renewable/Renewable Synchronous Distributed Generation

Pirouzi¹,

Shahi²,

Zadeh³

et al. 2021

Preprint

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“…The equivalent PSAI phase angle of the IIG may range between 0 and 180 • . Under certain circumstances, θ n1 may be very close to the boundary between the positive and negative operation zones, which may lower the sensitivity of the directional relay-or even cause mal-operation [15,16]. As a result, the phase angle of the equivalent PSAI is no longer 90 • , and the performance of the directional relay based on the PSFC may be affected.…”

Section: The Effect Of Iig Fault Characteristics On the Directional Rmentioning

confidence: 99%

“…Based on [15,18,19], the equivalent PSAI of the IIG is influenced by the control strategy, the fault condition, the load current, and so on. If ∆θ can be ignored (cos ∆θ = 1, sin ∆θ = 0), the simplified expression of the equivalent PSAI phase angle is shown in Equation (16): According to the LVRT requirement, the IIG needs to provide reactive power to support the voltage [20], i.e., Q re f > 0; thus, arg∆Z 1 is located at 0~180 • .…”

Section: The Effect Of Iig Fault Characteristics On the Directional Rmentioning

confidence: 99%

“…The directional relay based on the PSFC is not suitable for the distribution network with IIG integration. In [15], the influence of IIGs on the directional relay based on the PSFC was analyzed. The authors pointed out that the phase angle of the equivalent positive sequence abrupt impedance (PSAI) of the IIG will vary from 0 to 180 • , which may lower the sensitivity of the directional relay-or even cause its mal-operation.…”

mentioning

confidence: 99%

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An Improved Directional Relay Adapted to a Distribution Network with IIG Integration

Zhu

Wang

Zhao³

et al. 2019

Energies

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The integration of distributed generation (DG) into a distribution network changes the network's topology. Three-stage current protection for a radial distribution network cannot meet the requirements of relay protection for a distribution network with DG. A directional relay that is based on the positive sequence fault component (PSFC) can effectively identify faults in the positive and negative directions and can be used to solve the adaptability problem with three-stage current protection in a multi-source distribution network. However, DG and the traditional generators have different fault characteristics and are affected by different control strategies, which may lower the sensitivity of a directional relay based on the PSFC or even cause mal-operation. Focusing on this problem, this paper proposes an improved directional relay that is adapted to a distribution network with inverter-interfaced generation (IIG) integration. The improved scheme divides the operation zone of the directional relay based on the PSFC into sensitive and insensitive areas. If the result of a phase comparison is located in the insensitive area, further identification is needed according to a comparison of the current amplitudes. Simulation experiments are carried out based on PSCAD/EMTDC, and their results verify the correctness of the proposed scheme.Energies 2019, 12, 3345 2 of 14 in [11,12]. Unfortunately, [9-12] do not consider the low-voltage ride through (LVRT) requirement of DGs. The traditional DOP may mal-operate in the cases of a wind farm increasing the reactive power output [13]. Reference [13] uses a load encroachment function as a solution, but the function does not consider the effect of high transition resistance. To summarize, problems with directional overcurrent protection may arise in the following two situations:•A high-impedance ground fault, which may result in difficulties with identifying the direction of the fault; • A change in the reactive power output of inverter-interfaced generators (IIGs), which may cause the mal-operation of the traditional directional overcurrent relay.To improve the traditional directional overcurrent protection, the directional relay based on the positive sequence fault component (PSFC) has been widely used due to its ability to withstand transition resistance [14].However, the fault characteristics of DGs are affected by the control strategies, which are different from conventional generators. The directional relay based on the PSFC is not suitable for the distribution network with IIG integration. In [15], the influence of IIGs on the directional relay based on the PSFC was analyzed. The authors pointed out that the phase angle of the equivalent positive sequence abrupt impedance (PSAI) of the IIG will vary from 0 to 180 • , which may lower the sensitivity of the directional relay-or even cause its mal-operation. Unfortunately, no effective solution has been proposed yet.In view of the low sensitivity or mal-operation of the directional relay based on the PSFC for a distribution ...

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A two‐stage IIDG fault control scheme considering the fault direction identification in active distribution networks

Guo

2022

IEEJ Transactions Elec Engng

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In traditional power systems, the positive sequence fault component (PSFC) based criteria is often used to identify the fault directions. If the PSFC impedance angle of the inverter‐interfaced distributed generator (IIDG) is between 0 and 90°, the traditional PSFC‐based criteria will remain applicable in active distribution networks (ADNs). However, due to the diversity of the IIDG fault control mode and the uncertainty of the positive sequence voltage variation caused by faults, the PSFC impedance angle of IIDG is difficult to determine. To solve this problem, this paper proposes a two‐stage fault control scheme for IIDG. At different stages, IIDGs select different power references to meet different requirements. In the first stage, the PSFC impedance angle of IIDG is fixed to a given value, thereby maintaining the applicability of the PSFC‐based criteria in ADN. The detailed power reference calculation method of IIDG is given for this stage. In the second stage, IIDGs can select different fault control modes to support the fault voltage flexibly. By using the proposed two‐stage IIDG fault control scheme, the protection devices can accurately identify the fault direction in ADNs, which is verified by the MATLAB simulation results. © 2022 Institute of Electrical Engineers of Japan. Published by Wiley Periodicals LLC.

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Influence of Inverter-Interfaced Renewable Energy Generators on Directional Relay and an Improved Scheme

Cited by 113 publications

References 31 publications

Security-Constrained Optimal Protection Coordination for Dual-Setting Digital Directional Overcurrent Relays in the Distribution Network Including Non-Renewable/Renewable Synchronous Distributed Generation

Security-Constrained Optimal Protection Coordination for Dual-Setting Digital Directional Overcurrent Relays in the Distribution Network Including Non-Renewable/Renewable Synchronous Distributed Generation

An Improved Directional Relay Adapted to a Distribution Network with IIG Integration

A two‐stage IIDG fault control scheme considering the fault direction identification in active distribution networks

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