Distribution feeders form the last leg of the bulk power system and have the responsibility of providing reliable power to the customers. These feeders experience voltage drops due to a combination of feeder length, load distribution, and other factors. Traditionally, voltage drop was a major concern. Now, due to an ever-increasing PV penetration, overvoltage has also become a major concern. This limits the amount of solar PV that may be integrated. Few solutions exist to improve the voltage profile, where the most common is the use of voltage control devices like shunt capacitors and voltage regulators. Due to a large number of design parameters to be considered, the determination of the numbers and locations of these devices is a challenging problem. Significant research has been done to address this problem, utilizing a wide array of optimization techniques. However, many utilities still determine these locations and numbers manually. This is because most algorithms have not been adequately validated. The validation of a voltage profile design (VPD) algorithm has been presented here. The validation of this algorithm was carried out on a set of statistically relevant feeders. These feeders were chosen based on the results obtained from a feeder taxonomy study using clustering analysis. The algorithm was found to be effective in enhancing the amount of solar PV a feeder may host, while still maintaining all the voltages within the ANSI standard limits. Furthermore, the methodology adopted here may also be used for the validation of other algorithms. / Master of Science / Utilities have the responsibility of providing reliable power supply to their customers. Traditionally, bulk power was generated and transmitted over long distances incurring losses and voltage drops along the way. Now, with the integration of distributed energy resources, particularly solar photovoltaic (PV) generators at the customer locations, overvoltage has also become a problem. This requires adoption of measures which can help in maintaining the voltages within standard limits. Several options exist to compensate for these voltage issues, the most commonly used is voltage control devices like capacitor banks and voltage regulators. However, determining the required numbers of these devices and their appropriate locations is a challenging problem. Even though a number of algorithms have been proposed to give automated solutions to this problem, most utilities still use a manual approach. This is because these algorithms have not been validated on a statistically relevant set of feeders. To solve this issue, the validation of a voltage profile design (VPD) algorithm is presented in this thesis. The ability of this algorithm to enhance the amount of PV that may be connected to a distribution network has been validated on a set of feeders. The feeders were chosen based on the results obtained from clustering analysis, a machine learning concept. The cost effectiveness of this algorithm has also been investigated and significant savings were observed. Furthermore, the methodology adopted here can be easily extended for the validation of other algorithms as well.

The purpose of this bachelor thesis is to assess whether it is possible to create a simplified model that estimates the hosting capacity of a low-voltage grid. The Simplified model is compared with a more elaborate model created by the Built Environment Energy Systems Group (BEESG) at Uppsala University. The Simplified model takes three easily obtainable variables into account. The model created by BEESG allows us to observe both the amount of photovoltaic (PV) power that is installed as well as the voltages in each bus in a grid. The hosting capacity is found by gradually increasing the amount of PV power installed in a low-voltage grid until overvoltage is reached. Simulations with BEESG’s model are done for a week in July when the PV generation has its peak and the load is generally low. The Simplified model is created using linear regression with the calculated values from the BEESG’s model as a reference. The report shows that the Simplified model will give an estimation of the low-voltage grid’s hosting capacity that is comparable to the value calculated with BEESG’s model. The results show that it is rarely the low-voltage grid that restricts the installation of PV facilities and that a high self-consumption is advantageous regarding to the grids hosting capacity.

Detta arbete har med hjälp av acceptansgränser uppskattat hur mycket mikroproduktion som kan installeras i ett lågspänningsnät och resultatet presenteras som en karta över ett referensområde. Arbetet visar att det trots ett mycket starkt elnät i huvudsak är acceptansgränsen för spänningshöjning som kommer att vara begränsande. Det läggs fram tre förslag på åtgärder som underlättar införandet mikroproduktion. Mätning för att uppskatta återstående marginal till acceptansgränsen, vilket sedan kan fungera som ett beslutsunderlag för att tillåta mer installerbar effekt. Justering av transformatorns nominella spänning, vilket frigör utrymme för mer produktion. Möjligheten till begränsning av produktion under kritiska timmar medför att mer installerbar effekt kan tillåtas och det finns mer tid för genomtänkta investeringar. / This work has estimated the amount of microgeneration that may be installed in a low voltage grid based on hosting capacity limits and presents an overview of a reference area. The work shows that despite a very strong power grid, it is essentially the hosting capacity for voltage increase that will limit microgeneration production. Three proposals are given for measures that facilitate the introduction of microgeneration. Measurements to estimate the remaining margin to the hosting capacity limit, which serves as a decision base to allow more installable effect. Adjustment of the transformer's rated voltage, which increases the hosting capacity and allows more production. Production curtailment during critical hours means that more installable power can be allowed and there is more time for thoughtful investments.

This thesis provides a tool to determine the maximum capacity, of a given power grid, when connecting distributed photovoltaic parks including the optimal allocation of the parks taking the power grid configuration into account. This tool is based on a computational model that evaluates the hosting capacity of the given grid through power flow simulations. The tool also integrates a geographic information system that links suitable land areas to nearby substations that can host photovoltaic parks. The mathematical model was tested on different cases in the municipality of Herrljunga, Sweden, where it was determined to be possible to connect 47 photovoltaic parks of 1MWp to the power grid as well as the most appropriate substations to allocate them to without the need for grid reinforcements. Additionally, the concept of grid cost allocation is presented and briefly discussed while analysing the results in relation to national energy targets.

Detta arbete sammanfattar och redovisar ett arbetssätt för att bedöma vilken spänningshöjning som uppstår i tre radiella mellanspänningsnät på grund av den nettoeffekt som avges från solcellsanläggningar i de sammankopplade lågspänningsnäten. Hur anläggningarna är placerade antas vara efter hur abonnenterna är fördelade i mellanspänningsnäten. Spänningshöjningen som sker i mellanspänningsnäten är viktig att veta om då den kan medföra att marginalen till acceptabel spänningsnivå minskar i svaga punkter i näten vilket leder till ökad risk för att gränsvärden till långsamma spänningsvariationer och överspänning kan överskridas i abonnenters anslutningar till elnäten. Metoden bygger på ett iterativt tillvägagångssätt där nätens olika punkter undersöks och den som påverkas mest blir gränssättande för nätet. Resultaten påvisade skillnader mellan olika nät beroende på ledningsresistanser och antal abonnenter samt hur dessa är fördelade och hur nettoflöden av aktiv effekt ser ut i näten tillsammans med spänningshöjningen i var nod fram till slutpunkten. Med hjälp av dessa nettoflöden kunde riktlinjer tas fram och användas som rekommendationer för vilka storlekar på anläggningar som kan komma att begränsa mellanspänningsnäten. / This work summarizes and presents a method for assessing the voltage increase that occurs in three radial medium voltage networks due to the net power emitted from photovoltaic systems in the interconnected low voltage networks. How the production is located is assumed to be according to how the users are distributed in the medium voltage networks. The voltage increase that occurs in the medium voltage networks is important to know as it can lead to a decrease of the margin to acceptable voltage levels in weak points in the networks. The method is based on an iterative approach where the various points of the network are examined and the one that affects the most becomes the boundary for the network. Results showed differences between networks depending on line-resistances and number of users and how these are distributed and how net flows of active power cause the voltage increase in each node up to the end point. With the help of these net flows, guidelines could be drawn up and create recommendations size of photovoltaic systems that may limit the medium-voltage networks.

Electric vehicles (EVs) are increasing in popularity and play an important role in decarbonizing the transport sector. However, a growing EV fleet can cause problems for power grids as the grids are not initially designed for EV charging. The potential of a power grid to accommodate EV loads can be assessed through hosting capacity (HC) analysis. The HC is grid specific and varies, therefore it is necessary to conduct analysis that reflects local conditions and covers uncertainties and correlations over time. This theses aims to investigate the HC for EVs in existing residential power grids, and to gain a better understanding of how it varies based on how the EVs are implemented and charged. The work is in collaboration with a distribution system operator (DSO) and is based on two case studies using real-life data reflecting conditions in Swedish grids. Combinations of different HC assessment methods have been used and the HC is evaluated based on cable loading, transformer loading and voltage deviation. Additionally, the study investigated three distinct charging strategies: charging on arrival, evenly spread charging over whole connection period, and charging at the lowest spot price.  The results show that decisions on acceptable voltage deviation limit can have a large influence on the HC as well as the charging strategy used. A charging strategy based on energy prices resulted in the lowest HC, as numerous EVs charging simultaneously caused high power peaks during low spot price periods. Charging on arrival was the second worst strategy, as the peak power coincided with household demand. The best strategy was to evenly spread out the charging, resulting in fewer violations for 100% EV implementation compared to the other two strategies for 25% EV implementation.  The findings underscore the necessity for coordinated charging controls for EV fleets or diversified power tariffs to balance power on a large scale in order to use the grids efficiently.

Electric vehicles (EVs) are increasing in popularity and play an important role in decarbonizing the transport sector. However, a growing EV fleet can cause problems for power grids as the grids are not initially designed for EV charging. The potential of a power grid to accommodate EV loads can be assessed through hosting capacity (HC) analysis. The HC is grid specific and varies, therefore it is necessary to conduct analysis that reflects local conditions and covers uncertainties and correlations over time. This theses aims to investigate the HC for EVs in existing residential power grids, and to gain a better understanding of how it varies based on how the EVs are implemented and charged. The work is in collaboration with a distribution system operator (DSO) and is based on two case studies using real-life data reflecting conditions in Swedish grids. Combinations of different HC assessment methods have been used and the HC is evaluated based on cable loading, transformer loading and voltage deviation. Additionally, the study investigated three distinct charging strategies: charging on arrival, evenly spread charging over whole connection period, and charging at the lowest spot price.  The results show that decisions on acceptable voltage deviation limit can have a large influence on the HC as well as the charging strategy used. A charging strategy based on energy prices resulted in the lowest HC, as numerous EVs charging simultaneously caused high power peaks during low spot price periods. Charging on arrival was the second worst strategy, as the peak power coincided with household demand. The best strategy was to evenly spread out the charging, resulting in fewer violations for 100% EV implementation compared to the other two strategies for 25% EV implementation.  The findings underscore the necessity for coordinated charging controls for EV fleets or diversified power tariffs to balance power on a large scale in order to use the grids efficiently.

Dans cette thèse, les mesures de tension fournies par l'infrastructure de comptage avancé (Advanced Metering Infrastructure, AMI) sont utilisées pour contrôler un régleur en charge situé à la sous station HTA/BT. La thèse présente une méthode simple permettant de sélectionner les clients basse tension pour lesquels les mesures de tension sont utilisées comme une entrée au contrôleur du régleur en charge. Le procédé mis au point tient compte de la charge et de la topologie du réseau. En outre, une méthode simple pour créer des courbes réalistes et statistiquement correctes pour les études de réseaux est présenté. Les méthodes créées ont été testées en utilisant des données réelles de réseaux basse tension sur un logiciel très utilisé dans le secteur de la distribution d'électricité ont conduit à des résultats encourageants; quelques clients par réseau basse tension doivent être surveillés afin d’estimer avec une grande précision où se situe les extremums de tension sur le réseau.Cette méthodologie est également utilisée pour estimer la capacité d'accueil de génération d'énergie photovoltaïque dans un réseau à basse tension donné.Dans la première partie, l'évolution de la capacité d'accueil en utilisant trois types de contrôle de tension différents; un régleur en charge de cinq et neuf positions et le contrôle de la tension à travers les générateurs photovoltaïques, sont étudiés. L'étude considère deux cas différents pour le placement et le dimensionnement des générateurs photovoltaïques dans un réseau basse tension. Les résultats sur 38 réseaux basse tension sont fournis.Dans la deuxième partie, les capacités d'accueil de 631 réseaux basse tension, situés dans une région métropolitaine française, sont analysés en utilisant un régleur en charge de cinq et neuf positions.Le travail a été réalisé en collaboration avec Électricité Réseau Distribution France (ERDF), le principal opérateur du réseau de distribution français. Toutes les études présentées dans la thèse reposent sur les données réelles de fonctionnement normal. En outre, toutes les études sont mises en œuvre sur un logiciel largement utilisé dans l'industrie de la distribution d'énergie.Comme une partie introductive aux réseaux basse tension, la thèse fournit une vue générale sur le système électrique français. De plus, la thèse présente un certain nombre de technologies sélectionnés en tenant compte des réseaux basse-tension qui semblent prometteurs pour le futur. / In this thesis, voltage measurements provided by the advanced metering infrastructure (AMI) are used to control an on-load tap changer located at the secondary substation. The thesis presents a practical and a straightforward method of selecting the low voltage customers whose voltage measurements are used as an input to the controller of the on-load tap changer. The developed method takes into account the load and the topology of the network. Furthermore, a simple method of creating synthetic and statistically correct load curves for networks studies is presented. The created methods have been tested by using real data of low voltage networks on a common platform in the power distribution industry leading to encouraging results; a few customers per low voltage network should be monitored in order to achieve accurate voltage measurements.This methodology is further applied to estimate the hosting capacity of photovoltaic power generation in a given low voltage network.In the first part, the evolution of the hosting capacity by using three different types of voltage control; an on-load tap changer of five and nine tap positions and voltage control through photovoltaic power generators, is studied. The study considers two different cases for placing and sizing the photovoltaic generators in a low voltage network. The results of 38 low voltage networks are provided.In the second part, the hosting capacities of 631 low voltage networks, located in a French metropolitan area, are analysed by using an on-load tap changer of five and an on-load tap changer of nine tap positions.The work has been together with Électricité Réseau Distribution France (ERDF), the major French distribution system operator. All studies presented in the thesis are based on the real operational data of the company. Moreover, all studies are implemented on a platform that is widely used in the power distribution industry.As an introductory part to low voltage networks, the thesis provides a general view about the French power system. In addition, the thesis presents a number of selected technologies considering low voltage networks that seem promising in the future.

Increasing amounts of solar power connected to the low-voltage network will adversely affect the performance of the network. The two impacts that will most often set the limit are overvoltage with the customers and overloading the distribution transformer. In this work, alternative methods have been studied for determining when a transformer is overloaded, to allow more solar power to be connected to the low-voltage network, i.e., increasing the hosting capacity for solar power.A limit-based method on the highest temperature inside the transformer (the hotspot temperature) and a method based on the loss-of-life of the transformer insulation due to hotspot temperatures above the design temperature are those alternative methods in this study. These methods are known as "dynamic transformer rating", a technology proposed in the literature but with very little practical experience in distribution networks.Two models were developed and implemented in MATLAB: a thermal model of the transformer calculating the hotspot temperature for a given time series of loading and ambient temperature; and a model for the loss-of-life of the winding insulation for given time series of the hotspot temperature. These models have been applied to existing distribution networks: measured consumption patterns with high time resolution (10-minute time step) for nine different distribution transformers for 1.5 years (network operator); measured ambient temperature (SMHI); and solar-power production calculated from satellite measurements (Renewables Ninja).For these nine distribution transformers, the time series of the hotspot temperature and the loss-of-life over the 1.5 years have been calculated for different values of the solar power installed capacity on the low-voltage side of the distribution transformer. The resulting time series are used to estimate the hosting capacity for solar power of a 200 kVA transformer. Using the existing design methods, the hosting capacity is 200 kW. Once that value is reached, the further connection of solar power should be stopped until a larger transformer is available. According to IEC design methods, the hosting capacity is about 270 kW using a limit to the hotspot temperature. This value somewhat depends on the loading patterns of the transformer before the connection of solar power. Once that value is reached, the further connection should again be stopped. Even for installed capacity exceeding 270 kW, the loss of life of the transformer insulation is still small and acceptable. This allows for further connection of PV without the immediate need to replace the transformer. Even values up to 350 or 400 kW may be acceptable, but a limit based on loss-of-life will require a detailed risk analysis as the pre-solar loading of the transformer is shown to play an important role.This work has shown that dynamic transformer rating allows more solar power to be connected to a distribution network than using classical rating methods without unacceptable risk for transformer loss-of-life.

The Swedish Energy Agency has a target to increase solar photovoltaics (PV) power production by up to 5-10% of the total electricity demand by the year 2040. The PV potential for the residential market is high and its contribution to the total installed PV capacity is expected to increase significantly. The technical requirements should be met to keep high reliability and good power quality at the customers, therefore, it is important for planning reasons to proactively find the maximum amount PV power that can be connected at each low-voltage network without violating the performance of the grid. This amount is known as the hosting capacity. A method for PV hosting capacity estimation by taking overvoltage and transformer overload as performance indices was developed in this thesis. The method does not require any knowledge about the topology of the network. The overload hosting capacity can be estimated for any combination of customers having PV power and for the overvoltage hosting, the minimum at each penetration level can be estimated. The method was implemented on four low-voltage networks located in a typical Vattenfall medium-voltage network and the comparison of the estimation results to a power flow simulation showed good correspondence. It was shown how the impact of PV power in adjacent secondary substations can be accounted for. Using SS-EN50160 voltage limits, the studied networks were able to handle 3-7 times the PV penetration level needed (8 kWp at 20% of the customers) to achieve the national goal in Sweden without grid investments.