Participation in energy demand response programs requires an active role by users of residential appliances: they contribute flexibility in appliance usage as the means to adjust energy consumption and improve Smart Grid reliability. Understanding the collective potential that appliance-level flexibility has on Smart Grid reliability is challenging and complex. Physical characteristics of appliances, usage preferences, habits, and lifestyle are socio-technical factors that influence system-wide reliability coming often at the expense of users' comfort, i.e. thermal. This paper studies appliance-level flexible scheduling and specifically the following research questions: (i) How flexible are users in scheduling their appliances to improve Smart Grid reliability? (ii) How do users' comfort requirements affect the contributions of flexibility and as a result the collective action of improving Smart Grid reliability? (iii) Which appliances have the highest regulatory impact on Smart Grid? (iv) Can flexibility further improve Smart Grid reliability compared to simply operating individual appliances more efficiently? And finally, (v) what is the impact of varying users' participation on the collective action of improving reliability? To address these questions, a distributed optimisation scheme is studied to coordinate the selection of multiple appliance-level schedules representing users' self-determined flexibility. Experimental evaluation using a novel dataset shows that higher user flexibility significantly improves Smart Grid reliability with the oven having the highest system-wide potential for this. Compared to an existing efficiency scheme for kettles, flexible coordinated scheduling shows further improvements in reliability. These new findings have implications for the design of more cost-effective and granular demand response programs in participatory and decentralised Smart Grids.
Smart Grids and demand response programs are often considered to be technical in nature. However, recent research has emphasised the socio-technical aspects of Smart Grids @cite_28 , and how demand response programs can be designed to be more bottom-up, and user-centred. It is argued that user flexibility does not only depend on the appliances and monetary incentives @cite_24 ; but additionally it depends on individual characteristics and behaviour @cite_57 , conventions @cite_29 , and social practices involving the appliances @cite_52 . However, capturing such information based on historical data can be very challenging. Thus, this paper utilises appliance-level day-ahead scheduling via a personalised scheduling agent for each user. Using this scheduling agent, users directly determine their schedules, flexibility, usage preference, scheduling constraints, and comfort vs. reliability preference, on a daily basis. While this approach does require a higher level of engagement from users, recent research has shown that values such as increased control and autonomy can improve users' acceptance and participation in such programs @cite_24 @cite_35 @cite_38 .
@cite_35 @cite_38 @cite_28 @cite_29 @cite_52 @cite_57 @cite_24
2722817 2339116839 2296333757 2068060907
The widespread adoption of demand response enabled appliances and thermostats can result in significant reduction to peak electrical demand and provide potential grid stabilization benefits. GE has developed a line of appliances that will have the capability of offering several levels of demand reduction actions based on information from the utility grid, often in the form of price. However due to a number of factors, including the number of demand response enabled appliances available at any given time, the reduction of diversity factor due to the synchronizing control signal, and the percentage of consumers who may override the utility signal, it can be difficult to predict the aggregate response of a large number of residences. The effects of these behaviors can be modeled and simulated in open-source software, GridLAB-D, including evaluation of appliance controls, improvement to current algorithms, and development of aggregate control methodologies. This report is the first in a series of three reports describing the potential of GE's demand response enabled appliances to provide benefits to the utility grid. The first report will describe the modeling methodology used to represent the GE appliances in the GridLAB-D simulation environment and the estimated potential for peak demand reduction at various deployment levels. The second and third reports will explore the potential of aggregated group actions to positively impact grid stability, including frequency and voltage regulation and spinning reserves, and the impacts on distribution feeder voltage regulation, including mitigation of fluctuations caused by high penetration of photovoltaic distributed generation and the effects on volt-var control schemes. Demand response on the residential market is becoming a solution to adapt customer consumption to the offer available and therefore lower the electricity peak prices. Tariff incentives and direct load control of residential air-conditioners and electric heaters are flexible solutions to reduce the peak demand. To include residential demand response resources in planning operators, quantifying the demand reduction is becoming a major issue for all electrical stakeholders. Current methods are based on day or weather matching, regressions and control group approaches. In general, methods using available data from a control group give more accurate results. With the introduction of smart meters, the electric utilities generate a large amount of quality data, available almost in real time. In this paper, we suggest using these available residential load curves to select a control group based on individual load curves. One of the advantages of our method is that the selected control group could adapt at anytime to the number of individuals belonging to the demand reduction program, as this number evolves with customers entering and leaving the program. Constrained regression methods and an algorithm are developed and evaluated on real data, providing a reliable solution for an operational use. Significant changes in the power generation mix are posing new challenges for the balancing systems of the grid. Many of these challenges are in the secondary electricity grid regulation services and could be met through demand response (DR) services. We explore the opportunities for a water distribution system (WDS) to provide balancing services with demand response through pump scheduling and evaluate the associated benefits. Using a benchmark network and demand response mechanisms available in the UK, these benefits are assessed in terms of reduced green house gas (GHG) emissions from the grid due to the displacement of more polluting power sources and additional revenues for water utilities. The optimal pump scheduling problem is formulated as a mixed-integer optimisation problem and solved using a branch and bound algorithm. This new formulation finds the optimal level of power capacity to commit to the provision of demand response for a range of reserve energy provision and frequency response schemes offered in the UK. For the first time we show that DR from WDS can offer financial benefits to WDS operators while providing response energy to the grid with less greenhouse gas emissions than competing reserve energy technologies. Using a Monte Carlo simulation based on data from 2014, we demonstrate that the cost of providing the storage energy is less than the financial compensation available for the equivalent energy supply. The GHG emissions from the demand response provision from a WDS are also shown to be smaller than those of contemporary competing technologies such as open cycle gas turbines. The demand response services considered vary in their response time and duration as well as commitment requirements. The financial viability of a demand response service committed continuously is shown to be strongly dependent on the utilisation of the pumps and the electricity tariffs used by water utilities. Through the analysis of range of water demand scenarios and financial incentives using real market data, we demonstrate how a WDS can participate in a demand response scheme and generate financial gains and environmental benefits. Most of the existing demand-side management programs focus primarily on the interactions between a utility company and its customers users. In this paper, we present an autonomous and distributed demand-side energy management system among users that takes advantage of a two-way digital communication infrastructure which is envisioned in the future smart grid. We use game theory and formulate an energy consumption scheduling game, where the players are the users and their strategies are the daily schedules of their household appliances and loads. It is assumed that the utility company can adopt adequate pricing tariffs that differentiate the energy usage in time and level. We show that for a common scenario, with a single utility company serving multiple customers, the global optimal performance in terms of minimizing the energy costs is achieved at the Nash equilibrium of the formulated energy consumption scheduling game. The proposed distributed demand-side energy management strategy requires each user to simply apply its best response strategy to the current total load and tariffs in the power distribution system. The users can maintain privacy and do not need to reveal the details on their energy consumption schedules to other users. We also show that users will have the incentives to participate in the energy consumption scheduling game and subscribing to such services. Simulation results confirm that the proposed approach can reduce the peak-to-average ratio of the total energy demand, the total energy costs, as well as each user's individual daily electricity charges.