Vandewalle J.,EnergyVille Joint Venture of VITO NV and KU Leuven |
D'Haeseleer W.,Catholic University of Leuven
Energy Conversion and Management | Year: 2014
Smart grids are often regarded as an important step towards the future energy system. Combined heat and power (CHP) or cogeneration has several advantages in the context of the smart grid, which include the efficient use of primary energy and the reduction of electrical losses through transmission. However, the role of the gas network is often overlooked in this context. Therefore, this work presents an analysis of the impact of a massive implementation of small scale (micro) cogeneration units on the gas demand at distribution level. This work shows that using generic information in the simulations overestimates the impact of CHP. Furthermore, the importance of the thermal storage tank capacity on the impact on the gas demand is shown. Larger storage tanks lead to lower gas demand peaks and hence a lower impact on the gas distribution network. It is also shown that the use of an economically led controller leads to similar results compared to classical heat led control. Finally, it results that a low sell back tariff for electricity increases the impact of cogeneration on the gas demand peak. © 2013 Elsevier Ltd. All rights reserved. Source
Zapata Riveros J.,Catholic University of Leuven |
Zapata Riveros J.,EnergyVille Joint Venture of VITO NV and KU Leuven |
Donceel R.,Catholic University of Leuven |
Van Engeland J.,Catholic University of Leuven |
And 2 more authors.
Energy Conversion and Management | Year: 2015
In order to ensure reliable operation of the electric grid, it is required to keep the balance between total generation and consumption of power in real-time. This task is performed by the transmission system operator. Nowadays, with the large penetration of intermittent generation on the electric grid there is a need to increase the flexibility of the system in order to ensure the balance. The present study develops a methodology to provide near real-time balancing services making use of an aggregation of micro-CHP devices. The controller of the aggregator bids electricity into the day-ahead market using the expected heat demand and spot market prices. The main focus of this work is on the near real-time optimization which is performed during the actual day. This optimization provides the opportunity to obtain extra profits by rescheduling the operation of the aggregator. The rescheduling is done in order to compensate the total system imbalance. To achieve this, every time step, the aggregator evaluates the system demand for up or down regulation and decides if it is profitable to adjust its position to provide balancing services to the power system. The methodology is applied to a case study that resembles the actual situation of the energy market and CHP installations in Belgium. The results show that using the near real-time balancing optimization a total cost decrease of 5% can be achieved depending on the season. This conclusion is valid even if there is an increase of the gas prices and if the actual governmental support on CHPs is not taken into account. © 2014 Elsevier Ltd. All rights reserved. Source
Nuytten T.,EnergyVille Joint Venture of VITO NV and KU Leuven |
Nuytten T.,Flemish Institute for Technological Research |
Moreno P.,University of Lleida |
Vanhoudt D.,EnergyVille Joint Venture of VITO NV and KU Leuven |
And 5 more authors.
Applied Thermal Engineering | Year: 2013
The efficiency of micro-combined heat and power (micro-CHP) systems can be increased by decoupling the production of electricity and heat by means of thermal energy storage (TES) systems where heat that is not needed during the production period can be stored for later use. The aim of this article is to evaluate the use of different TES units when coupled to micro-CHP systems. An experimental study was carried out to evaluate the thermal behavior of different TES units for coupling with a micro-CHP system. A cylindrical TES tank was used to compare the performance of two phase change materials (PCMs) with different melting temperature and encapsulation method, while using a water-filled unit as a reference scenario. The first concept consists of cylindrical PCM tubes while the second uses small spherical PCM capsules, both commercially available products. The analysis involves three different tests: constant inlet temperature, constant power, and partial capacity loading. The results are evaluated on the basis of a comparison between inlet and outlet temperatures, charging time and thermal energy stored by the TES units. The PCM tubes are characterized by a higher capacity when a low thermal power is applied while the PCM capsules are able to store more energy at higher power. The operating temperatures in partial loading tests indicate that the incorporation of PCM storage units in a smart grid environment may be beneficial from a thermal systems point of view. © 2013 Elsevier Ltd. All rights reserved. Source
Zapata J.,Catholic University of Leuven |
Zapata J.,EnergyVille Joint Venture of VITO NV and KU Leuven |
Vandewalle J.,Catholic University of Leuven |
Vandewalle J.,EnergyVille Joint Venture of VITO NV and KU Leuven |
And 2 more authors.
Applied Thermal Engineering | Year: 2014
The penetration of a large amount of distributed generation (DG) technologies with intermittent output, such as photovoltaic installations and wind turbines, yields an important challenge to the electric grid. It is believed that aggregating them with controllable technologies such as cogeneration devices (CHP) can help to balance fluctuations of renewable energy. This work evaluates the ability of a virtual power plant (VPP) to reduce the imbalance error of renewable generators. The study is undertaken in a VPP that consists of several cogeneration devices and photovoltaic (PV) installations. The virtual power plant operator bids electricity into the day-ahead market using the forecast for solar irradiation and for the thermal demand. During the actual day, the imbalance due to deviations between the forecasted electricity delivered and the real output has to be settled in the balancing market. Thus, in order to compensate these errors and possible economic drawbacks, the operation of the CHP is adjusted periodically in a so called reschedule. Two different rescheduling strategies are compared against a 'reference scenario' in which the imbalance error is settled in the market. The first one ('forced strategy') aims at reducing the imbalance error every time step regardless of the imbalance prices. The second ('economic strategy') considers the imbalance prices and takes only action if it is economically appropriate and thus intends to reduce the total operational cost. The results show that the rescheduling technique is able to reduce the imbalance error (up to 90% depending on the season and the strategy). Additionally, the total operational cost is estimated. However, the nowadays imbalance prices only lead to a minor financial advantage that is unlikely to motivate real life operators to perform a rescheduling strategy. © 2013 Elsevier Ltd. Source
Patteeuw D.,Catholic University of Leuven |
Patteeuw D.,EnergyVille Joint Venture of VITO NV and KU Leuven |
Bruninx K.,Catholic University of Leuven |
Bruninx K.,EnergyVille Joint Venture of VITO NV and KU Leuven |
And 7 more authors.
Applied Energy | Year: 2015
Active Demand Response (ADR) can contribute to a more cost-efficient operation of, and investment in, the electric power system as it may provide the needed flexibility to cope with the intermittent character of some forms of renewables, such as wind. One possibly promising group of demand side technologies in terms of ADR are electric heating systems. These systems could allow to modify their electrical load pattern without affecting the final, thermal energy service they deliver, thanks to the thermal inertia in the system. One of the major remaining obstacles for a large scale roll-out of ADR schemes is the lack of a thorough understanding of interactions between the demand and supply side of the electric power system and the related possible benefits for consumers and producers. Therefore, in this paper, an integrated system model of the electric power system, including electric heating systems (heat pumps and auxiliary resistance heaters) subjected to an ADR scheme, is developed, taking into account the dynamics and constraints on both the supply and demand side of the electric power system. This paper shows that only these integrated system models are able to simultaneously consider all technical and comfort constraints present in the overall system. This allows to accurately assess the benefits for, and interactions of, demand and supply under ADR schemes. Furthermore, we illustrate the effects not captured by traditional, simplified approaches used to represent the demand side (e.g., price elasticity models and virtual generator models) and the supply side (e.g., electricity price profiles and merit order models). Based on these results, we formulate some conclusions which may help modelers in selecting the approach most suited for the problem they would like to study, weighing the complexity and detail of the model. © 2015 Elsevier Ltd. Source