Pádraig Lyons

Integrating Electrical Energy Storage Into Coordinated Voltage Control Schemes for Distribution Networks

In this paper, a coordinated voltage control scheme utilizing electrical energy storage (EES) is presented, for future distribution networks with large, clustered distributions of low carbon technologies (LCTs) in terms of both feeder and phase location. The benefits of the EES integrated scheme over conventional voltage control schemes are demonstrated by realizing a set of network scenarios on a case study network both in simulation and in network in the loop (NIL) emulation at a smart grid laboratory facility. The case study uses a rigorously validated model of an actual GB distribution network with multiple EES installations. It was found that the EES integrated voltage control scheme is able to provide increased capability over conventional voltage control schemes and increase the value of EES to network operation.

Small Scale Energy Zones and the Impacts of High Concentrations of Small Scale Embedded Generators

A recent study has indicated that installed micro-generation capacity in the UK could grow to as much as 8 GW by 2015. Clearly, this significant growth will present a number of challenges and opportunities for the electricity industry. Current research in the New and Renewable Energy Group at Durham University seeks to address these issues. This paper describes this research and introduces the concept of an SSEZ (small scale energy zone) and presents a series of IPSA+ models to support this concept. An SSEZ is defined as a distribution network zone containing a significant number of controllable small scale generators, distributed energy storage units and loads. Algorithms will be developed to take an integrated approach to the control of each of these three elements in order to increase the value of SSEGs in terms of economic return, environmental benefit and contribution to network operation. The IPSA+ distribution network models feature high concentrations of SSEGs but are conventional type distribution networks, as opposed to the envisaged active distribution network of an SSEZ. These models are used to evaluate the impact on steady-state voltage rise of a range of SSEG penetrations. This paper describes the SSEZ concept, the IPSA+ models and the laboratory based SSEZ under development at Durham University

Distribution network voltage control using energy storage and demand side response

This paper presents a new application of electrical energy storage (EES) systems and demand side response (DSR) operating collaboratively to enable voltage control within distribution networks. This work has been carried out as part of the Customer Led Network Revolution (CLNR) project which is funded by Ofgems Low Carbon Networks Fund. Modelling and simulation work is presented, which demonstrates the operation of the control system. Field trials will be carried out in 2012, to implement and evaluate the control systems on the case study network.

A practical implementation of a distributed control approach for microGrids.

Abstract Public low voltage feeders containing a mixture of several micro-sources, distributed energy storage units (ESUs) and controllable loads, which appear to the upstream distribution network as controllable entities, are known as MicroGrids. Through intelligent co-ordination of micro-generators and ESUs, coupled with demand side management techniques, MicroGrids have the potential to offer significant improvements in the commercial value and environrnental impact of installed micro-generators. Furthermore, using appropriate active control techniques, MicroGrids could potentially overcome the low voltage distribution network constraints associated with high levels of micro-generation. The reseazch described in this paper builds upon previous research carried out at Durham University, which proposed a preliminary distributed control approach for MicroGrids. The fast steps in this approach have now been implemented using agent technology on the laboratory based Experimental MicroGrid at Durham Universi...

Robust Scheduling Scheme for Energy Storage to Facilitate High Penetration of Renewables

This paper presents a robust scheduling scheme for energy storage systems (ESSs) deployed in distribution networks to facilitate high penetrations of renewable energy sources (RES). This scheme schedules the charging and discharging of an ESS cognizant of state-of-charge (SoC) limits, transmission line real time thermal ratings (RTTR), and voltage constraints. Robust optimization (RO) has been adopted to deal with the uncertainty of RES output, load, and RTTR. Two methods have been introduced to estimate the tradeoff between the cost and the probability of constraint violations. The proposed scheduling scheme is tested on the IEEE 14 and 118 busbar networks with real load, generation, and RTTR profiles through Monte Carlo simulation (MCS). Test results show that the proposed scheme is able to minimize or curtail the probability of constraint violation to a desired level. In contrast, classical optimal power flow (OPF) approaches which do not consider uncertainty, when coupled with RTTR and ESS, result in a low PoS. At the same time, compared to conservative OPF approaches, the proposed scheme reduces the power and energy requirement of ESS.

Viability of using energy storage for frequency regulation on power grid

This project is about the development and integration of a real-time network simulator in the laboratory using hardware in the loop (HIL) for the purpose of frequency regulation. Frequency regulation is done using the energy storage system (ESS) and a real-time network test bed developed in the smart energy laboratory in Newcastle University. An IEEE Test System was built in the OPAL-RT network simulator to mimic the power grid with renewable energy sources. The study demonstrates the viability of using an ESS to regulate the frequency under an increased penetration of renewable energy sources.