The challenges of estimating the impact of distributed energy resources flexibility on the TSO/DSO boundary node operating points

Silva, João; Sumaili, Jean; Bessa, Ricardo J.; Seca, Luís; Matos, Manuel; Miranda, Vladimiro

doi:10.1016/j.cor.2017.06.004

Cited by 73 publications

(60 citation statements)

References 25 publications

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“…The grid topology defines the shape of the FOR; however, analysing this impact is not in the scope of the paper. Such an analysis was already performed in [16] and [47].

similarity = \frac{area (FO {normalR}_{normalRS} \cap normalFO {normalR}_{normalLFA})}{area (FO {normalR}_{normalRS} \cup normalFO {normalR}_{normalLFA})} \cdot 100 %

…”

Section: Numerical Resultsmentioning

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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“…The grid topology defines the shape of the FOR; however, analysing this impact is not in the scope of the paper. Such an analysis was already performed in [16] and [47].

similarity = \frac{area (FO {normalR}_{normalRS} \cap normalFO {normalR}_{normalLFA})}{area (FO {normalR}_{normalRS} \cup normalFO {normalR}_{normalLFA})} \cdot 100 %

…”

Section: Numerical Resultsmentioning

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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“…As distribution networks feature ever more generation and potentially, storage penetrations, the need for balancing and ancillary service procurement deep into the network increases [31]. Owing to the number of LV feeders utility companies own, any forecasting method will need to be optimized for speed and memory use in order to scale up for deployment across distribution networks.…”

Section: Dso Perspectivementioning

confidence: 99%

Non-Gaussian Residual Based Short Term Load Forecast Adjustment for Distribution Feeders

2020

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The evolving role for electricity network operators means that load forecasting at the distribution level has become increasingly important, presenting the need for anticipation of the behavior of highly dynamic and diversely distributed loads. The commonly held assumption of Gaussian residuals in forecasting does not always hold for distribution network loads, increasing the uncertainty in balancing a system at this network level. To reduce the operational impact of forecast errors, this paper utilizes different multivariate joint probability distributions to capture the intra-day dependency structure of forecast residuals. Transforming these to the conditional form enables forecast corrections to be made at variable horizons even in the absence of the forecast model. Improvements in accuracy are demonstrated on benchmark load forecast models at distribution level low voltage substations. A practical distribution system application on scheduling embedded energy storage shows substantial reductions in grid imports and hence costs to distribution level customers from utilizing the proposed intraday correction approach. INDEX TERMS Load modeling, power systems, renewable generation.

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“…MG owners desire to gain benefits through energy transactions and scheduling. However, there are requirements (such as minimum bid size volume) to take part in the wholesale market, e.g., the minimum contract in the Nordic day-ahead market is 0.1 MWh/h-these requirements might not be met by many small-scale MGs that desire to participate in the wholesale market [8,9]. Hence, it is possible to participate in wholesale market transactions through an active resource portfolio.…”

Section: Problem Statementmentioning

confidence: 99%

“…In this study, the market operation problem defined by (9) and (10) can be mathematically described as (11) to maximize the MGs' revenue, and (12) to minimize the DSO's cost:…”

Section: Problem Formulation In the Dgsmmentioning

confidence: 99%

A Multi-Market-Driven Approach to Energy Scheduling of Smart Microgrids in Distribution Networks

Yue

Anvari‐Moghaddam

et al. 2019

Sustainability

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In order to coordinate the economic desire of microgrid (MG) owners and the stability operation requirement of the distribution system operator (DSO), a multi-market participation framework is proposed to stimulate the energy transaction potential of MGs through distributed and centralized ways. Firstly, an MG equipped with storage can contribute to the stability improvement at special nodes of the distribution grid where the uncertain factors (such as intermittent renewable sources and electric vehicles) exist. The DSO is thus interested in encouraging specified MGs to provide voltage stability services by creating a distribution grid service market (DGSM), where the dynamic production-price auction is used to capture the competition of the distributed MGs. Moreover, an aggregator, serving as a broker and controller for MGs, is considered to participate in the day-ahead wholesale market. A Stackelberg game is modeled accordingly to solve the price and quantity package allocation between aggregator and MGs. Finally, the modified IEEE-33 bus distribution test system is used to demonstrate the applicability and effectiveness of the proposed multi-market mechanism. The results under this framework improve both MGs and utility.

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The challenges of estimating the impact of distributed energy resources flexibility on the TSO/DSO boundary node operating points

Cited by 73 publications

References 25 publications

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

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

Non-Gaussian Residual Based Short Term Load Forecast Adjustment for Distribution Feeders

A Multi-Market-Driven Approach to Energy Scheduling of Smart Microgrids in Distribution Networks

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