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Prof. Dr.-Ing. Matthias Huber

Professor

EC 2.04

0991/3615-8911


Sprechzeiten

siehe Consultation Hours in Ilearn: https://ilearn.th-deg.de/course/view.php?id=14504 (normalerweise Dienstags 9:00-9:45)


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Zeitschriftenartikel

  • Kueppers. M.
  • S. Paredes Pineda
  • M. Metzger
  • Matthias Huber
  • S. Paulus
  • H. Heger
  • S. Niessen

Decarbonization pathways of worldwide energy systems – Definition and modeling of archetypes

In: Applied Energy vol. 285 pg. 116438.

  • (2021)

DOI: 10.1016/j.apenergy.2021.116438

Energy system models help to find the optimal technology mixes for decarbonization strategies in countries worldwide. To reduce the modeling effort and analyze as many countries as possible, this paper proposes a novel approach of energy system archetypes which can be directly evaluated. These archetypes classify similar countries worldwide independently from their geographic location. Advantages of this idea are the setup of a transferable global database allowing for data reconstruction between countries, market size estimations, and the ability to compare peer countries facing similar challenges. To enable such modeling, a framework is developed in which the archetypes are defined, standardized modeling rules are developed, and the results are evaluated for validation. In a benchmark against simple geographic classifications, the presented clustering approach, which results in 15 archetypes, improves the variance between all countries and their corresponding archetypes by 44% compared to the variance between the countries and their geographic sub-regions. The model results of these archetypes state the need of balancing technologies for the daily cycle of photovoltaic generation and the general importance of flexibility in future decarbonized energy systems. Overall, the results confirm that archetypes are an adequate approach to derive the set of solutions for the decarbonization of worldwide countries.
  • Europan Campus Rottal-Inn
  • NACHHALTIG
  • DIGITAL
Beitrag (Sammelband oder Tagungsband)

  • M. Küppers
  • M. Metzger
  • Matthias Huber
  • S. Paulus

Archetypes of Country Energy Systems

pg. 1-6.

  • (2019)

DOI: 10.1109/PTC.2019.8810765

Global challenges as decarbonization, the integration of renewables or an increasing electrification are confronting countries worldwide. Based on an analysis of different energy system models, archetypes of country energy systems are identified as an approach to simplify modeling the global challenges for most countries around the world. Applying a modified K-means algorithm to a broad and transparent data basis of socio-economic, geographic/climatic and energy-related data leads to the definition of the archetypes. An exemplary clustering of 140 countries generating 15 archetypes underlines the existence of patterns in energy systems, which can e.g. be characterized by the climatic circumstances or the energy mix. Overall the archetypes represent a possibility to summarize countries on a global level, leading to a simplified modeling process of countries in energy system models, providing a common data basis for models and identifying common challenges of different countries.
  • Europan Campus Rottal-Inn
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Zeitschriftenartikel

  • C. Müller
  • A. Hoffrichter
  • L. Wyrwoll
  • C. Schmitt
  • M. Trageser
  • T. Kulms
  • D. Beulertz
  • M. Metzger
  • M. Durckheim
  • Matthias Huber
  • M. Küppers
  • D. Most
  • S. Paulus
  • H. Heber
  • A. Schnettler

Modeling framework for planning and operation of multi-modal energy systems in the case of Germany

In: Applied Energy vol. 250 pg. 1132-1146.

  • (2019)

DOI: 10.1016/j.apenergy.2019.05.094

In order to reach the goals of the United Nations Framework Convention on Climate Change, a stepwise reduction of energy related greenhouse gas emissions as well as an increase in the share of renewable energies is necessary. For a successful realization of these changes in energy supply, an integrated view of multiple energy sectors is necessary. The coupling of different energy sectors is seen as an option to achieve the climate goals in a cost-effective way. In this paper, a methodical approach for multi-modal energy system planning and technology impact evaluation is presented. A key feature of the model is a coupled consideration of the sectors electricity, heat, fuel and mobility. The modeling framework enables system planners to optimally plan future investments in a detailed transition pathway of the energy system of a country, considering politically defined climate goals. Based on these calculations, in-depth analyses of energy markets as well as electrical transmission and distribution grids can be performed using the presented optimization models. Energy demands, conversion and storage technologies in households, the Commerce, Trade and Services (CTS) area and the industry are modeled employing a bottom-up modeling approach. The results for the optimal planning of the German energy system until 2050 show that the combination of an increased share of renewable energies and the direct electrification of heat and mobility sectors together with the use of synthetic fuels are the main drivers to achieve the climate goals in a cost-efficient way.
  • Europan Campus Rottal-Inn
  • NACHHALTIG
  • DIGITAL
Beitrag (Sammelband oder Tagungsband)

  • O. Walter
  • Matthias Huber
  • Kueppers. M.
  • A. Tremel
  • S. Becker

Energy system design for deep decarbonization of a sunbelt city by using a hybrid storage approach

In: Proceedings of the 13th International Renewable Energy Storage Conference 2019 (IRES 2019). null (Atlantis Highlights in Engineering) pg. 183-190.

  • (2019)
With continuously falling cost of renewable power generation and ambitious decarbonization targets, renewable sources are about to rival fossil fuels for energy supply. For a high share of fluctuating renewable generation, large-scale energy storage is likely to be required. In addition to selling electricity, the reliable supply of heat and cold is a further interesting revenue pool, which makes hybrid storage technologies an interesting option. The main feature of hybrid energy storage – as defined here - is to offer charging and especially discharging in different forms of energy by combining different charging, discharging and storage devices. They can address various demands (e.g. electricity and cold) simultaneously. Two hybrid storages, pumped thermal energy storage (PTES) and power-to-heat-to-x (x: heat and/or electricity) energy storage (PHXES), are investigated based on a techno-economic analysis within this work. Both hybrid storage technologies are charged with electricity and can supply heat and electricity during discharging. They are implemented into a simplified energy system model of a prototype city in the earth’s sunbelt in the year 2030 to find a cost-optimal configuration. Different cases are evaluated: a power-to-power case (P2P), where only an electric demand must be addressed and a power-to-power-and-cooling (P2P&C) case, where the electric demand from the P2P case is divided into a residual electric demand and a cooling demand. For both cases, a natural gas-based benchmark scenario and a decarbonized, renewable-based scenario including the hybrid energy storage technologies are calculated. Both, total expenditures and CO2 emissions are lower in the P2P&C scenarios compared to P2P scenarios. PHXES plays a major role in both cases. PTES is part of the cost-optimal solution in the P2P&C decarb scenario, only if its specific cost are further decreased.
  • Europan Campus Rottal-Inn
  • NACHHALTIG
  • DIGITAL
Beitrag (Sammelband oder Tagungsband)

  • N. Vespermann
  • Matthias Huber
  • S. Paulus
  • M. Metzger
  • T. Hamacher

The Impact of Network Tariffs on PV Investment Decisions by Consumers

pg. 1-5.

  • (2018)

DOI: 10.1109/EEM.2018.8469944

The increasing amount of self-produced energy reduces the customer base of network utilities. Assuming constant grid costs, network charges have to be increased in systems applying volumetric network tariffs. In order to understand the cost recovery problem of utilities, it is crucial to analyze consumers' PV investment and operation decisions as sources of self-produced energy. This work proposes a mathematical framework that determines PV investment by consumers subject to the day-ahead market. Volumetric and capacity network tariffs are considered, which are altered by consumers' day-ahead market demand. The optimal PV investment from a central planner's perspective serves as a benchmark. The results show that a volumetric network tariff incentivizes inefficient investments in distributed PV systems, which causes all consumers' energy costs to increase. In contrast, a capacity network tariff reduces these incentives as consumers cannot offset their expected burden of network costs by installing PV systems.
  • Europan Campus Rottal-Inn
  • NACHHALTIG
  • DIGITAL
Beitrag (Sammelband oder Tagungsband)

  • K. Siala
  • E. Baik
  • Matthias Huber
  • T. Hamacher
  • S. Benson

Optimizing the Californian Power System according to the Renewable Portfolio Standards for 2030 and beyond

  • (2018)
  • Europan Campus Rottal-Inn
  • NACHHALTIG
  • DIGITAL
Beitrag (Sammelband oder Tagungsband)

  • T. Deetjen
  • M. Webber
  • Matthias Huber

Optimizing capacity extensions in power systems: A case study of Bavaria and a comparison to Texas

pg. 1-6.

  • (2017)

DOI: 10.1109/EEM.2017.7981908

As the German Energiewende policy enters the latter stages of its goal to dismantle the country's nuclear power plant fleet, the southern state of Bavaria must decide how it will replace its nuclear generation capacity. This study extends a renewable capacity expansion model that was initially developed to find optimal extensions of wind and solar generation and transmission for Texas, United States. Here, additional options for the development of the Bavarian electricity supply are added: combined-heat-and-power (CHP), improving transmission connections to the non-Bavarian German generator fleet, and constructing new natural gas combined cycle (CCGT) power plants within Bavaria. The model's solution suggests that an optimal mix includes 3.5 GW of transmission to the non-Bavarian generator fleet, 6.0 to 9.5 GW of new CCGT capacity, and 8.5 to 10.0 GW of transmission capacity to the on-shore wind resources of the Schleswig-Holstein state in northern Germany, depending on the CO 2 price. Compared to the model results for Texas, Bavaria's system is less sensitive to a CO 2 price in both the optimal system configuration and the resulting emissions. While Texas emissions can be reduced by 55% with a CO 2 price increase from 10 to 100 $/ton, the reduction in Bavaria is only 28% with a price increase from 0 to 100 EUR/ton.
  • Europan Campus Rottal-Inn
  • DIGITAL
  • NACHHALTIG
Zeitschriftenartikel

  • R. Brandenberg
  • Matthias Huber
  • M. Silbernagl

The summed start-up costs in a unit commitment problem

In: EURO Journal on Computational Optimization vol. 5 pg. 203-238.

  • (2017)

DOI: 10.1007/s13675-016-0062-2

We consider the sum of the incurred start-up costs of a single unit in a Unit Commitment problem. Our major result is a correspondence between the facets of its epigraph and some binary trees for concave start-up cost functions CU, which is bijective if CU is strictly concave. We derive an exponential H-representation of this epigraph, and provide an exact linear separation algorithm. These results significantly reduce the integrality gap of the Mixed Integer formulation of a Unit Commitment Problem compared to current literature.
  • Europan Campus Rottal-Inn
  • DIGITAL
Graue Literatur / Bericht / Report

  • T. Hamacher
  • T. Hartmann
  • K. Siala
  • Matthias Huber
  • P. Kuhn
  • L. Stolle

Gesicherte Stromversorgung in Bayern . Technischer Bericht im Auftrag des Bayerischen Staatsministeriums für Wirtschaft, Landesentwicklung und Energie

Lehrstuhl für Erneuerbare und Nachhaltige Energiesysteme

  • 2016 (2016)
Kernenergie ist nach wie vor eine wichtige Säule der Stromversorgung in Bayern. Im Jahr 2013 betrug ihr Beitrag noch knapp die Hälfte der gesamten Bruttostromerzeugung. Damit stellt sich die Frage, wie die Stromversorgung in Bayern nach Stilllegung aller Kernkraftwerke bis zum Jahr 2022 sichergestellt werden kann. Im Rahmen dieser Studie wurden vier verschiedene Möglichkeiten anhand von Szenarien analysiert, die aus technischer Sicht grundsätzlich denkbar sind: Bau von HGÜ Leitungen, Bau von Gaskraftwerken, Ausbau der Erneuerbaren Energien, sowie dezentraler Ausbau von KWK-Anlagen. Für jedes Szenario wurde dabei zunächst mittels eines Optimierungsmodells die kostengünstigste Betriebsweise aller Kraftwerke im europäischen Verbundnetz unter Berücksichtigung von Einschränkungen durch die zugrunde gelegte Infrastruktur berechnet. Diese Daten bilden die Grundlage für einen Vergleich der Optionen anhand verschiedener Kriterien. Sofern keine zusätzlichen Kraftwerkskapazitäten in Bayern über die aktuelle Planunghinaus aufgebaut werden, muss in Zukunft knapp die Hälfte des Strombedarfs nach Bayern importiert werden. Die Ausweitung der Übertragungskapazitäten mittels neuer HGÜ-Leitungen konnte in diesem Zusammenhang als Maßnahmemit Vorteilenidentifiziert werden, da in diesem Fall der Ausgleich innerhalb Deutschlandserleichtert und damit die Gefahr von unterschiedlichen Preiszonen in Deutschland reduziert sowie die Stromversorgung Bayerns zu wettbewerbsfähigen Preisen gewährleistet wird. Der Zubau von weiteren Gaskraftwerken hat auf den ersten Blick nur einen begrenzten Nutzen, da diese Kraftwerke unter derzeitigen Marktbedingungen nur selten eingesetzt würden. Allerdings können sie mit geringem finanziellem Aufwand einen deutlichen Beitrag zur Versorgungssicherheit (sichere Leistungsbereitstellung) leisten. Der Ausbau der Erneuerbaren Energien über die derzeitigen Ziele hinaus bzw. der Einsatz einer Vielzahl von dezentralen Blockheizkraftwerken steht in Verbindung mit vergleichsweise hohen Kostensowie im letzteren Fall zusätzlich mit einem hohen Ausstoß von klimaschädlichen Emissionen in Bayern. In anderen Regionen Europas wird dadurch allerdings die Emission von klimaschädlichen Gasen überproportional reduziert. Beide Möglichkeiten beinhalten zudem Herausforderungender konkreten Umsetzung aufgrund von umfänglichen gesetzlichen Anpassungen und einer großen Anzahl von neu zu installierenden Anlagen. Auch wenn im Rahmen der Studie nur vier Szenarienuntersucht wurden, erlauben die Ergebnisse die Schlussfolgerung, dass vorteilhafte Synergieeffekte in der sinnvollen Kombination eines Ausbaus der Kapazitäten des Übertragungsnetzes, der Erneuerbaren Energien –in Bayern insbesondere der Photovoltaik– und von dezentralen KWK-Anlagen liegen.
  • Europan Campus Rottal-Inn
  • NACHHALTIG
  • DIGITAL
Zeitschriftenartikel

  • P. Kuhn
  • Matthias Huber
  • J. Dorfner
  • T. Hamacher

Challenges and opportunities of power systems from smart homes to super-grids

In: Ambio vol. 45 pg. 50-62.

  • (2016)

DOI: 10.1007/s13280-015-0733-x

The world’s power systems are facing a structural change including liberalization of markets and integration of renewable energy sources. This paper describes the challenges that lie ahead in this process and points out avenues for overcoming different problems at different scopes, ranging from individual homes to international super-grids. We apply energy system models at those different scopes and find a trade-off between technical and social complexity. Small-scale systems would require technological breakthroughs, especially for storage, but individual agents can and do already start to build and operate such systems. In contrast, large-scale systems could potentially be more efficient from a techno-economic point of view. However, new political frameworks are required that enable long-term cooperation among sovereign entities through mutual trust. Which scope first achieves its breakthrough is not clear yet.
  • Europan Campus Rottal-Inn
  • DIGITAL
  • NACHHALTIG
Zeitschriftenartikel

  • Matthias Huber
  • C. Weissbart

On the optimal mix of wind and solar generation in the future Chinese power system

In: Energy vol. 90 pg. 235-243.

  • (2015)

DOI: 10.1016/j.energy.2015.05.146

China is one of the largest and fastest growing economies in the world. Until now, the corresponding growth of electricity consumption has been mainly provided by coal. However, as national reserves are limited and since burning coal leads to severe environmental problems, the employment of alternative sources of energy supply has become an important part of the Chinese energy policy. Recent studies show that wind energy alone could meet all of China's electricity demand. While our results validate these findings with regard to annual production, we look at the hour-by-hour resolution and uncover a major limitation: wind generation will not match the demand at every given point in time. This results in significant periods with over- and undersupply. Our study shows that combining wind and solar generation in the power system reduces overproduction significantly and increases the capacity credit of the combined VRE (variable renewable energy sources). The article demonstrates that up to 70% of VRE comprising 20–30% solar generation in the form of photovoltaics (PV) can be integrated into China's electricity system with moderate storage requirements. We encourage planners to consider those findings in their long-term planning in order to set up a sustainable power system for China at low costs.
  • Europan Campus Rottal-Inn
  • NACHHALTIG
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Vortrag

  • Matthias Huber

The German Energy Transition: Current Trends and Challenges . Invited lecture

Harvard Energy Policy Group Boston, MA, USA

  • 2014 (2014)
  • Europan Campus Rottal-Inn
  • DIGITAL
  • NACHHALTIG
Beitrag (Sammelband oder Tagungsband)

  • Matthias Huber
  • F. Sanger
  • T. Hamacher

Coordinating smart homes in microgrids: A quantification of benefits

pg. 1-5.

  • (2013)

DOI: 10.1109/ISGTEurope.2013.6695357

A growing number of households are seeking energy autonomy and economic benefits by installing micro-CHP and PV generators, as well as battery storage units in their so-called smart homes. An option to further increase benefits, is to install a community microgrid and coordinate smart homes intelligently. To quantify this increase, we apply numerical simulations using real-world data for household loads in a temporal resolution of 15-minutes. In systems consisting of CHP-units, the degree of electricity autonomy rises from 50% to 80% through installing a microgrid, allowing lucrative CHP operation. In PV-based systems, the benefits are fewer and if battery storage is installed additionally, they almost disappear completely. As a consequence, intelligently managed microgrids are as valuable option for the integration of microgeneration as long as decentralized battery storage is not profitable and thus not employed.
  • Europan Campus Rottal-Inn
  • DIGITAL
  • NACHHALTIG
Beitrag (Sammelband oder Tagungsband)

  • H. Mangesius
  • S. Hirche
  • Matthias Huber
  • T. Hamacher

A framework to quantify technical flexibility in power systems based on reliability certificates

pg. 1-5.

  • (2013)

DOI: 10.1109/ISGTEurope.2013.6695460

Power systems are increasingly stressed by variable and unpredictable generation from various sources. We identify the qualitative framework of flexibility as an adequate tool to specify requirements that allow the system to handle this variability. An open problem is the quantification of technical flexibility that incorporates limitations from transmission system and component behavior in contrast to existing copper plate supply and demand balance approaches. We develop such a quantitative method for single components on the basis of a priori specified reliability criteria. Our framework bases on a combined static power flow and small signal stability analysis. In a perturbative approach we derive sensitivity-based formula for eigenvalue variations under nonlinear changes of steady power flow set points. To this end, we define rigorously the terms flexibility metric and technical flexibility of single components. We provide an algorithmic procedure for computation of tolerance ranges of individual system components such that the overall behavior remains reliable.
  • Europan Campus Rottal-Inn
  • NACHHALTIG
  • DIGITAL
Vortrag

  • Matthias Huber

Combining LP and MIP approaches to model the impacts of renewable energy generation on individual thermal power plant operation

In: 2013 IEEE General Meeting Power & Energy Society

Vancouver, BC, Canada

  • 21.07.2013 (2013)
  • Europan Campus Rottal-Inn
  • NACHHALTIG
  • DIGITAL
Beitrag (Sammelband oder Tagungsband)

  • B. Neudecker
  • P. Wimmer
  • Matthias Huber
  • T. Hamacher

Economic Assessment of Range Extension Technologies for BEVs in 2020

  • (2013)
This paper focusses on an energy economic analysis of battery electric vehicles (BEVs), specifically investigating their means to extend the driving range on long distance trips in the year 2020. Three range extension technologies – fast charging, battery switching and driving with an on-board micro internal combustion engine – are hereby compared. The implemented simulation tool ZEVS models the particularities of BEVs in 27 European countries, whereby specifically the methodologies for modelling the daily driving habits of medium and long distance trips and the additional power demand for heating (winter) and cooling (summer) are described. The resulting load curves are then incorporated in a further modelling tool, URBS-EU, which simulates a cost minimal power plant portfolio supplying renewable energy to BEV power demand. An in-depth results analysis shows that BEVs with battery switch technology are responsible for the least amount of CO2 emissions, have the lowest primary energy generation costs and integrate renewable energy feed-in most efficiently in comparison to the other two range extension alternatives.
  • Europan Campus Rottal-Inn
  • DIGITAL
  • NACHHALTIG
Beitrag (Sammelband oder Tagungsband)

  • S. Roon
  • Matthias Huber

Modeling Spot Market Pricing with the Residual Load

pg. 1-18.

  • (2010)
In this paper the effects of increasing feed-in of renewable energy sources on the spot market prices are assessed. The electricity prices are mainly determined by the consumer load (demand) and the respective marginal cost of the power plant fleet (supply). The efficiency and the fuel prices (including the costs for emission allowances) are the main factors for the marginal costs of power plants. It does not matter whether the feed-in of RES is modeled as supply without marginal cost or is subtracted from the consumer load. Decisive for the price is the load that has to be covered by conventional power plants, the so defined residual load. An observable correlation with coefficients of determination from 0.54 to 0.77 between the residual load and the spot market prices was shown in a linear regression in the years from 2007 - 2009. Interestingly, taking into account more data than consumer load and wind power feed-in for calculating the residual load does not lead to higher coefficients of determination in the years from 2007 to 2009. Hence, for price correlation analysis it is sufficient to model the residual load by the consumer load minus the feed-in of wind in the near future. However, for scenario calculations, we recommend considering the load of PV as well. Moreover, it is important to be aware that a change in power plant fleet is not regarded. The slope of the normalized spot market price over residual load is about 0.082 per GW Residual Load. That means that the feed-in of 1 GWh must-run power, e.g. wind, leads to a spot market price reduction of 2.33 €/MWh (assuming the mean natural gas price in 2008 of 28 €/MWh). The isolated analysis of the impact of changing the residual load from 2008 to 2020 shows a higher deviation in prices and a mean price reduction of 15 €/MWh. Changes in fuel prices and in the power plant fleet are not considered in this estimation.
  • Europan Campus Rottal-Inn
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Kernkompetenzen

  • Energiewirtschaft
  • Nachhaltige Energiesysteme
  • Modellierung und Optimierung von Energiesystemen
  • Intelligente Infrastruktur und intelligente Gebäude


Vita

Siemens AG, Corporate Technology Ifo Institut, Zentrum für Energie, Klima und Ressourcen TU München, Lehrstuhl für Erneuerbare Energiesysteme Forschungsaufenthalte in Stanford, UT Austin, NTU Singapore