On Feasibility and Flexibility Operating Regions of Virtual Power Plants and TSO/DSO Interfaces

Riaz, Shariq; Mancarella, Pierluigi

doi:10.1109/ptc.2019.8810638

Cited by 52 publications

(69 citation statements)

References 21 publications

(32 reference statements)

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“…The authors of [19] differentiate between a feasible operation region and the timedependent flexibility, which can be supplied in a certain time considering the actual status of the FPU as well as activation and ramp times. Monte-Carlo simulations are performed to identify the edges of the FOR polygon regarding different time horizons based on random control scenarios.…”

Section: Related Workmentioning

confidence: 99%

“…Monte-Carlo simulations are performed to identify the edges of the FOR polygon regarding different time horizons based on random control scenarios. The authors of [17] as well as [19] consider the specific technical and regulatory limits of flexibility capable devices for their active and reactive power supply at their current operating points.…”

Section: Related Workmentioning

confidence: 99%

“…Comparing the two categories of FOR determination methods (stochastic [15][16][17][18][19], optimization based [20][21][22][23][24][25][26][27][28][29]) the optimization-based approaches show advantages of the computation time and the identification of the concrete FOR contour (see [20,23]). The exact position of a point on the edge of the FOR as well as the order of the points are determined by using sampling strategies at the optimization-based approaches.…”

Section: Contributions Of This Articlementioning

confidence: 99%

See 2 more Smart Citations

Survey and Comparison of Optimization-Based Aggregation Methods for the Determination of the Flexibility Potentials at Vertical System Interconnections

et al. 2021

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The aggregation of operational active and reactive power flexibilities as the feasible operation region (FOR) is a main component of a hierarchical multi-voltage-level grid control as well as the cooperation of transmission and distribution system operators at vertical system interconnections. This article presents a new optimization-based aggregation approach, based on a modified particle swarm optimization (PSO) and compares it to non-linear and linear programming. The approach is to combine the advantages of stochastic and optimization-based methods to achieve an appropriate aggregation of flexibilities while obtaining additional meta information during the iterative solution process. The general principles for sampling an FOR are introduced in a survey of aggregation methods from the literature and the adaptation of the classic optimal power flow problem. The investigations are based on simulations of the Cigré medium voltage test system and are divided into three parts. The improvement of the classic PSO algorithm regarding the determination of the FOR are presented. The most suitable of four sampling strategies from the literature is identified and selected for the comparison of the optimization methods. The analysis of the results reveals a better performance of the modified PSO in sampling the FOR compared to the other optimization methods.

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Section: Related Workmentioning

confidence: 99%

Section: Related Workmentioning

confidence: 99%

Section: Contributions Of This Articlementioning

confidence: 99%

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Survey and Comparison of Optimization-Based Aggregation Methods for the Determination of the Flexibility Potentials at Vertical System Interconnections

et al. 2021

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“…[8][9][10][11][12] are directly applicable to generic polygonal shapes, yet the approach fails to integrate grid constraints, which is critical for the FIGURE 1 Schematic representation of the aggregated FOR and FXOR concepts applied to an ADN, based on the feasible and flexible capability charts ( [7,22]) computation of the FOR, as shown in [13]. To include grid constraints into the calculation, on one hand, a random sampling (RS) approach was proposed in [14], and replicated in [5,7]. The method is simple, yet time consuming due to the large number of iterations required to achieve results of good quality [15].…”

Section: Introductionmentioning

confidence: 99%

Computing the feasible operating region of active distribution networks: Comparison and validation of random sampling and optimal power flow based methods

Contreras

Rudion

2021

IET Generation Trans & Dist

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The feasible operating region (FOR) indicates the operation points that an active distribution network can achieve at the interconnection point with the transmission grid when operating flexible assets within it; without disturbing the stability of the grid itself. Even though the concept is not new, many novel methods to compute the FOR efficiently have been proposed in recent years, resulting in two main schools of thought: random sampling (RS) and optimal power flow (OPF) methods. Both approaches have their merits, yet no wide‐ranging analysis regarding scenarios in which each method could be best applied has been done so far. This paper focuses on performing such a comparison; however, capability charts of flexibility providing units and grids are usually modelled as irregular convex polygons, requiring some adaptation of the RS‐methods to allow for a proper comparison of the resulting feasible operating region. Correspondingly, new methods to adapt the extraction of random samples from generic capability charts are proposed in the paper. Using models of two radial distribution grids, both OPF‐ and RS‐based methods are compared and validated. Results show that RS methods are adequate for assessing small grids, especially with the proposed improvements, while OPF‐based methods excel in larger grids.

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“…That means that it can meet the need to change the frequency or respond to an event by increasing/decreasing the power output. The calculation of feasible and flexible operating regions and maximum grid support capacity for a VPP was demonstrated in [29]. However, the network operator may not see the expected change in the frequency following a response from the VPP: since (UR) and (DR) delivery by coordinated inverters alter local voltages, it will trigger inverters with passive control to change their output (as per local voltage control settings).…”

Section: Introductionmentioning

confidence: 99%

Interaction Between Coordinated and Droop Control PV Inverters

Lusis

Andrew

Liebman

et al. 2020

Proceedings of the Eleventh ACM International Conference on Future Energy Systems

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Autonomous droop control PV inverters have improved voltage regulation compared to the inverters without grid support functions, but more flexible control techniques will be required as the number of solar photovoltaic (PV) installations increases. This paper studies three inverter future deployment scenarios with droop control inverters, non-exporting inverters, and coordinated inverter control (CIC). The network operation and the interaction between various inverter control methods are studied by simulating inverter operation on two low-voltage networks. Considering 30% PV penetration as the base case, we demonstrate that coordinated inverters can mitigate overvoltages and voltage fluctuations caused by the tripping of passive inverters in 85% of PV location cases when at least as many coordinated as passive inverters are deployed on the 114-node test feeder. However, this rate reduced to 37% with the IEEE 906-node network demonstrating that the deployment of coordinated inverter control may not be able to reverse passive inverter-related voltage disturbances when the build-up of passive inverters has reached a certain threshold.The aggregated PV output from coordinated inverters can be also used to provide grid support services. When the low-voltage networks operate close to the upper voltage limits, the change in the power output from coordinated inverters following a regulation request may be partially offset by passive inverters. Considering an equal number of passive and coordinated inverters, this paper shows that for each unit of the down-regulation request delivered by coordinated inverters, passive inverter output may increase by up to 0.2 units and decrease by up to 0.45 units during coordinated inverter up-regulation.

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On Feasibility and Flexibility Operating Regions of Virtual Power Plants and TSO/DSO Interfaces

Cited by 52 publications

References 21 publications

Survey and Comparison of Optimization-Based Aggregation Methods for the Determination of the Flexibility Potentials at Vertical System Interconnections

Survey and Comparison of Optimization-Based Aggregation Methods for the Determination of the Flexibility Potentials at Vertical System Interconnections

Computing the feasible operating region of active distribution networks: Comparison and validation of random sampling and optimal power flow based methods

Interaction Between Coordinated and Droop Control PV Inverters

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