Abstract
The ability to manage loads can play a significant role in the future operation and planning of electricity networks. One way of unlocking this source of flexibility without directly involving thousands or millions of customers is to exploit the positive correlation between supplied voltage and demand, i.e., voltage-led load management. Distribution network operators, in particular, could achieve this by adequately controlling voltage regulation devices. Nonetheless, to quantify this it is key to understand the extent to which voltages can be changed (reduced) while considering the dependencies across different voltage levels. A methodology is proposed here to quantify the aggregated demand reduction unlocked by controlling primary substations considering the voltage interactions and constraints throughout the whole distribution network. Given the complexity and dimensions, the influence of the upstream network on primary substations and the effects on low voltage customers are analyzed separately whilst maintaining their dependencies. The methodology, developed within the largest UK load management trial, is applied to real 132 to 0.4 kV distribution networks adopting realistic load models. Results demonstrate not only the significance of the scheme as a source of flexibility but, crucially, that the interactions and constraints across voltage levels are key in its adequate time-varying quantification.
Highlights
T HE growing uptake of small-to-large scale renewable generation requires a paradigm shift in the planning and operation of future electricity networks
The methodology proposed in this work aims at quantifying the aggregated voltage-led demand reduction at the T-D interface, ΔPT −D (t), unlocked by controlling primary substations (MV) taking into account the interactions and constraints with HV and low voltage (LV) networks
The demand profiles in the case study were assumed to be unaffected by customer behavioral changes due to voltage reductions
Summary
T HE growing uptake of small-to-large scale renewable generation requires a paradigm shift in the planning and operation of future electricity networks. The limited hosting capacity of existing assets as well as the need for larger systemlevel reserve requirements are likely to require further sources of flexibility if significant investments are to be deferred or avoided [1], [2]. The direct involvement of a large number of customers is often needed to achieve significant benefits making the scalability of this approach a major challenge. Manuscript received October 17, 2016; revised February 8, 2017 and May 11, 2017; accepted June 3, 2017. Date of publication June 30, 2017; date of current version February 16, 2018.
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