A multi-agent model for assessing electricity tariffs

This paper describes the framework for modelling a multi-agent approach for assessing dynamic pricing of electricity and demand response. It combines and agent-based model with decision-making data, and a standard load-flow model. The multi-agent model described here represents a tool in investigating not only the relation between different dynamic tariffs and consumer load profiles, but also the change in behaviour and impact on low-voltage electricity distribution networks.The authors acknowledge the contribution of the EPSRC Transforming Energy Demand Through Digital Innovation Programme, grant agreement numbers EP/I000194/1 and EP/I000119/1, to the ADEPT project

ELECTRICITY TARIFFS IN GEORGIA

Article discusses electricity tariff setting methods, such as: «Rate of Return Regulation», «Price Cup Regulation», «Return Assets Base (RAB)» and «Cost Plus». Meet the interests of electricity producers and consumers are one of the indicators of the health of the electricity sector. At present, the Georgian electricity market is striving to harmonize with EU standards and established electricity tariff methodology should be use the best method to encourage investors to invest in the field and expand their infrastructure while ensuring the reliability and efficiency of electricity supply.Article discusses electricity tariff setting methods, such as: «Rate of Return Regulation», «Price Cup Regulation», «Return Assets Base (RAB)» and «Cost Plus». Meet the interests of electricity producers and consumers are one of the indicators of the health of the electricity sector. At present, the Georgian electricity market is striving to harmonize with EU standards and established electricity tariff methodology should be use the best method to encourage investors to invest in the field and expand their infrastructure while ensuring the reliability and efficiency of electricity supply

Information and energy policy preferences: a survey experiment on public opinion about electricity pricing reform in rural India

A common argument for the lack of economic reform in developing countries is popular opposition. If current economic policies are dysfunctional, could information about alternatives sway the voters? We examine if a simple argument emphasizing the need to increase electricity prices for improved supply can change public opinion in the case of India’s power sector reforms. The evidence comes from a survey experiment in rural Uttar Pradesh, which is both India’s largest state and has one of the lowest levels of household electrification. As expected, people respond to information about the relationship between electricity pricing, capacity investment, and reliability of supply by increasing their support for higher prices. However, no corresponding increase is observed for privatization of electricity generation. For external validity, we analyze an existing national survey on electricity privatization conducted in 2004/2005, finding patterns that support our argumen

Local Energy Communities in Spain: Economic Implications of the New Tariff and Variable Coefficients

[EN] The European Union advocates for legislative support to local energy communities. Measures include the promotion of dynamic energy allocation and discriminatory electricity tariffs such as the recent Spanish framework. However, the impact of these normative changes is not yet evaluated. This paper inquires into the impact of dynamic allocation coefficient and different electricity tariffs on the profitability of local energy communities. To do so, a linear optimisation model is developed and applied to real consumer data in Spain around a variable capacity photovoltaic generation plant. Comparing the economic performance of the static or variable power allocation under the effect of changing electricity tariffs. While both measures are beneficial, the new electricity tariffs result in larger profitability increases than the planned variable coefficients. The combination of measures allows for profitability improvements of up to 25% being complementary measures. However, installations that maximise the potential for electricity generation are still not as profitable due to the low purchase price of surplus energy. While discriminatory electricity price tariffs and variable allocation coefficients are positive measures, further measures are needed for these communities to install generation plants as large as the potential that each case allows.This work was supported in part by the Spanish public administration under the grant FPU2016/00962 and by the Catedra de Transicion Energetica Urbana (Las Naves-FVCiE-UPV)Manso-Burgos, Á.; Ribó-Pérez, DG.; Alcázar-Ortega, M.; Gómez-Navarro, T. (2021). Local Energy Communities in Spain: Economic Implications of the New Tariff and Variable Coefficients. Sustainability. 13(19):1055-1073. https://doi.org/10.3390/su131910555S10551073131

Modelling and design of local energy systems incorporating heat pumps, thermal storage, future tariffs, and model predictive control

The planning-level design of local energy systems requires sufficiently capable modelling tools which incorporate heat pumps, thermal storage, future electricity markets, and predictive control strategies. Gaps were identified in a review of existing local energy system tools: (i) ability to adapt and access source code; (ii) temperature dependence for heat pump models; (iii) stratification model for thermal storage models; (iv) modelling of evolving electricity markets; and (v) ability to explore predictive controls. A novel modelling tool, PyLESA, has been developed to tackle these gaps and to explore predictive and non-predictive controls, and existing and future electricity tariffs. PyLESA possesses the following modelling capabilities: resources, and electrical and heat demands; electricity production; heat pump; hot water tank; electricity tariffs; fixed order control (FOC); model predictive control (MPC); and KPIs. A sizing study for a proposed design of a district heating network was devised to showcase an application of PyLESA. Aims were to compare control strategies and electricity tariffs, and to identify an optimal size combination of heat pump and hot water tank. Comparisons between control strategies found that MPC offers savings over FOC. The lowest levelized cost of heat for the existing electricity tariffs was for the time-of-use tariff with MPC, 750kW heat pump and 500m3 hot water tank. A wind tariff, with a 1000kW heat pump and 2000m3 hot water tank, benefits from using MPC over the FOC: levelized heat costs reduce by 41.1%, and heat demand met by RES increases from 52.8% to 70.2%. It is shown that the proposed design can be sized using existing electricity tariffs, and additional hot water tank capacity added later to benefit from future tariffs. The results convey the advantage of combining flexible tariffs with optimally sized thermal storage and showcase PyLESA as capable of usefully aiding the design of local energy systems.The planning-level design of local energy systems requires sufficiently capable modelling tools which incorporate heat pumps, thermal storage, future electricity markets, and predictive control strategies. Gaps were identified in a review of existing local energy system tools: (i) ability to adapt and access source code; (ii) temperature dependence for heat pump models; (iii) stratification model for thermal storage models; (iv) modelling of evolving electricity markets; and (v) ability to explore predictive controls. A novel modelling tool, PyLESA, has been developed to tackle these gaps and to explore predictive and non-predictive controls, and existing and future electricity tariffs. PyLESA possesses the following modelling capabilities: resources, and electrical and heat demands; electricity production; heat pump; hot water tank; electricity tariffs; fixed order control (FOC); model predictive control (MPC); and KPIs. A sizing study for a proposed design of a district heating network was devised to showcase an application of PyLESA. Aims were to compare control strategies and electricity tariffs, and to identify an optimal size combination of heat pump and hot water tank. Comparisons between control strategies found that MPC offers savings over FOC. The lowest levelized cost of heat for the existing electricity tariffs was for the time-of-use tariff with MPC, 750kW heat pump and 500m3 hot water tank. A wind tariff, with a 1000kW heat pump and 2000m3 hot water tank, benefits from using MPC over the FOC: levelized heat costs reduce by 41.1%, and heat demand met by RES increases from 52.8% to 70.2%. It is shown that the proposed design can be sized using existing electricity tariffs, and additional hot water tank capacity added later to benefit from future tariffs. The results convey the advantage of combining flexible tariffs with optimally sized thermal storage and showcase PyLESA as capable of usefully aiding the design of local energy systems

High resolution performance analysis of micro-trigeneration in an energy-efficient residential building

Trigeneration has long been proposed as a means to improve energy-efficiency for large and medium sized buildings. To curb increasing energy demand in the residential sector, researchers are now focusing their attention on adapting trigeneration to residential buildings. Literature is full of examples pertaining to the performance of trigeneration in large and medium sized commercial buildings, however little is known on the performance of micro-trigeneration inside residential buildings, particularly under a range of operating conditions. To understand the influence that parameters such as changes in thermal and electrical loading or different plant configurations have on the performance of micro-trigeneration, this research makes use of a detailed model of a Maltese apartment building, and associated micro-trigeneration system. The performance of the model is simulated using a whole building simulation tool run at high-resolution minute time frequency over a number of different operating conditions and scenarios. Each scenario was then assessed on the basis of the system's energetic, environmental and economic performance. The results show that, compared to separate generation the use of a residential micro-trigeneration system reduces primary energy consumption by about 40%, but also that the system's financial performance is highly susceptible to the operating conditions

Impact of higher electricity tariffs on the profitability of electricity supply and distribution companies in Namibia.

Masters Degree. University of KwaZulu-Natal, Durban.This paper presents the effect of increased electricity tariffs on the profitability of electricity supply and distribution companies in Namibia. The Namibian electricity tariffs regarding time-of-use, setting and pricing have been compared with others countries, regionally, continentally and internationally. The time-of-use methodology and concepts benefit the consumers in terms of low tariffs at off-peak times, and discourage high consumption at peak time. This study investigated the way in which high electricity tariffs impacted the profitability of electricity utilities in Namibia. It analysed and interpreted questionnaires administered to thirteen employees of the three electricity supply and distribution companies in Namibia. The results show that the high electricity tariffs had negative effects on the companies’ profitability in the electricity supply and distribution sector in Namibia. The results, furthermore, reveal that the electricity supply and distribution companies in Namibia passed the increases on to their customers. Moreover, the study concludes that there were factors that contributed to the high electricity tariffs, such as political factors, sources of energy, the poor management of utilities and a shortage of resources. There was no relationship between the electricity tariffs and profitability and equity ratios

Consumers struggle to choose new types of electricity tariffs, but comparison tools can help1. ESRI Research Bulletin March 2020/06

The introduction of smart meters in Ireland will soon allow consumers to choose new types of electricity tariffs. Time-of-use tariffs charge different prices for electricity at different times of the day. While these tariffs can help consumers save money on their energy bills, their introduction will make energy tariff choices in Ireland more complicated. In collaboration with the Commission for Regulation of Utilities (CRU), the ESRI’s Behavioural Research Unit undertook a controlled behavioural experiment with a sample of the Irish consumers, to explore their tariff choices. It tested how likely consumers will be to choose new tariffs over existing and simpler tariffs, as well as testing their ability to choose the best tariff for their own electricity usage. The study also pre-tested online tools designed to help consumers make better energy choices

Poverty and environmental impacts of electricity price reforms in Montenegro

The Government of Montenegro is preparing an electricity tariff reform due to recent developments in the national and regional electricity markets. Electricity tariffs for residential consumers in Montenegro are likely to gradually increase by anywhere from 40 to over 100 percent. This significant price rise will impose a heavy burden on poor households and it may adversely affect the environment. In an ex-ante investigation of the welfare impact of this price increase on households in Montenegro, the authors show that the anticipated price increase will result in a significant increase in households'energy expenditures. A simulation of alternative policy measures analyzes the impact of different tariff levels and structures on the poor and vulnerable households in particular. Higher electricity prices could also significantly increase the proportion of households using fuelwood for space heating.Energy Production and Transportation,Electric Power,Environment and Energy Efficiency,Energy and Environment,Engineering