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Prof. Francisco Gonzalez-Longatt
Universitetet I Sørøst-Norge

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Research Keywords & Expertise

0 HVDC
0 Low Carbon Technologies
0 Protection Systems
0 Energy Storage Systems
0 Power Systems Operation

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Short Biography

Francisco M. Gonzalez-Longatt is currently a full professor in electrical power engineering and Founder and leader of the DIgEnSys-Lab (Digital Energy Systems Laboratory) at the Department of Electrical Engineering, Information Technology and Cybernetics, University of South-Eastern Norway, Norway.

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Journal article
Published: 16 August 2021 in Energies
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With the increasing penetration rate of Power Electronic Converter (PEC) based technologies, the electrical power systems are facing the problem of transient stability since the PEC based technologies do not contribute to the system inertia, and the proportion of synchronous generators (i.e., the source of inertia) is in decreasing rate. In addition, PEC based technologies’ components have poor inherent damping. It is very important to analyze the system characteristics of a power system to minimize the potential instabilities during the contingencies. This paper presents the parametric sensitivity analysis of the rotor angle stability indicators for the 39-bus New England power system. The indicators of rotor angle stability analysis such as critical fault clearing time (CCT), Eigenvalue points, damping ratio, frequency deviation, voltage deviation, and generator’s speed deviation are identified and analyzed for three case scenarios; each scenario has six sub-cases with different inertia constants. The results show that the CCTs for each component will be reduced if the inertia reduces at any section of a multi-machine power system. Although the applied three scenarios with six sub-cases are identified to be stable in this analysis, the decreasing inertia constant has significant impact on the power system dynamics.

ACS Style

Ashish Shrestha; Francisco Gonzalez-Longatt. Parametric Sensitivity Analysis of Rotor Angle Stability Indicators. Energies 2021, 14, 5023 .

AMA Style

Ashish Shrestha, Francisco Gonzalez-Longatt. Parametric Sensitivity Analysis of Rotor Angle Stability Indicators. Energies. 2021; 14 (16):5023.

Chicago/Turabian Style

Ashish Shrestha; Francisco Gonzalez-Longatt. 2021. "Parametric Sensitivity Analysis of Rotor Angle Stability Indicators." Energies 14, no. 16: 5023.

Journal article
Published: 08 August 2021 in Energies
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The reactive power control mechanisms at the smart inverters will affect the voltage profile, active power losses and the cost of reactive power procurement in a different way. Therefore, this paper presents an assessment of the cost–benefit relationship obtained by enabling nine different reactive power control mechanisms at the smart inverters. The first eight reactive power control mechanisms are available in the literature and include the IEEE 1547−2018 standard requirements. The ninth control mechanism is an optimum reactive power control proposed in this paper. It is formulated to minimise the active power losses of the network and ensure the bus voltages and the reactive power of the smart inverter are within their allowable limits. The Vestfold and Telemark distribution network was implemented in DIgSILENT PowerFactory and used to evaluate the reactive power control mechanisms. The reactive power prices were taken from the default payment rate document of the National Grid. Simulation results demonstrate that the optimal reactive power control mechanism provides the best cost–benefit for the daily steady-state operation of the network.

ACS Style

Martha Acosta; Francisco Gonzalez-Longatt; Manuel Andrade; José Torres; Harold Chamorro. Assessment of Daily Cost of Reactive Power Procurement by Smart Inverters. Energies 2021, 14, 4834 .

AMA Style

Martha Acosta, Francisco Gonzalez-Longatt, Manuel Andrade, José Torres, Harold Chamorro. Assessment of Daily Cost of Reactive Power Procurement by Smart Inverters. Energies. 2021; 14 (16):4834.

Chicago/Turabian Style

Martha Acosta; Francisco Gonzalez-Longatt; Manuel Andrade; José Torres; Harold Chamorro. 2021. "Assessment of Daily Cost of Reactive Power Procurement by Smart Inverters." Energies 14, no. 16: 4834.

Journal article
Published: 30 July 2021 in Energies
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The massive integration of variable renewable energy (VRE) in modern power systems is imposing several challenges; one of them is the increased need for balancing services. Coping with the high variability of the future generation mix with incredible high shares of VER, the power system requires developing and enabling sources of flexibility. This paper proposes and demonstrates a single layer control system for coordinating the steady-state operation of battery energy storage system (BESS) and wind power plants via multi-terminal high voltage direct current (HVDC). The proposed coordinated controller is a single layer controller on the top of the power converter-based technologies. Specifically, the coordinated controller uses the capabilities of the distributed battery energy storage systems (BESS) to store electricity when a logic function is fulfilled. The proposed approach has been implemented considering a control logic based on the power flow in the DC undersea cables and coordinated to charging distributed-BESS assets. The implemented coordinated controller has been tested using numerical simulations in a modified version of the classical IEEE 14-bus test system, including tree-HVDC converter stations. A 24-h (1-min resolution) quasi-dynamic simulation was used to demonstrate the suitability of the proposed coordinated control. The controller demonstrated the capacity of fulfilling the defined control logic. Finally, the instantaneous flexibility power was calculated, demonstrating the suitability of the proposed coordinated controller to provide flexibility and decreased requirements for balancing power.

ACS Style

Martha Acosta; Francisco Gonzalez-Longatt; Juan Roldan-Fernandez; Manuel Burgos-Payan. A Coordinated Control of Offshore Wind Power and BESS to Provide Power System Flexibility. Energies 2021, 14, 4650 .

AMA Style

Martha Acosta, Francisco Gonzalez-Longatt, Juan Roldan-Fernandez, Manuel Burgos-Payan. A Coordinated Control of Offshore Wind Power and BESS to Provide Power System Flexibility. Energies. 2021; 14 (15):4650.

Chicago/Turabian Style

Martha Acosta; Francisco Gonzalez-Longatt; Juan Roldan-Fernandez; Manuel Burgos-Payan. 2021. "A Coordinated Control of Offshore Wind Power and BESS to Provide Power System Flexibility." Energies 14, no. 15: 4650.

Journal article
Published: 27 July 2021 in Energies
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Today, the power system operation represents a challenge given the security and reliability requirements. Mathematical models are used to represent and solve operational and planning issues related with electric systems. Specifically, the AC optimal power flow (ACOPF) and the DC optimal power flow (DCOPF) are tools used for operational and planning purposes. The DCOPF versions correspond to lineal versions of the ACOPF. This is due to the fact that the power flow solution is often hard to obtain with the ACOPF considering all constraints. However, the simplifications use only active power without considering reactive power, voltage values and losses on transmission lines, which are crucial factors for power system operation, potentially leading to inaccurate results. This paper develops a detailed formulation for both DCOPF and ACOPF with multiple generation sources to provide a 24-h dispatching in order to compare the differences between the solutions with different scenarios under high penetration of wind power. The results indicate the DCOPF inaccuracies with respect to the complete solution provided by the ACOPF.

ACS Style

Diego Larrahondo; Ricardo Moreno; Harold Chamorro; Francisco Gonzalez-Longatt. Comparative Performance of Multi-Period ACOPF and Multi-Period DCOPF under High Integration of Wind Power. Energies 2021, 14, 4540 .

AMA Style

Diego Larrahondo, Ricardo Moreno, Harold Chamorro, Francisco Gonzalez-Longatt. Comparative Performance of Multi-Period ACOPF and Multi-Period DCOPF under High Integration of Wind Power. Energies. 2021; 14 (15):4540.

Chicago/Turabian Style

Diego Larrahondo; Ricardo Moreno; Harold Chamorro; Francisco Gonzalez-Longatt. 2021. "Comparative Performance of Multi-Period ACOPF and Multi-Period DCOPF under High Integration of Wind Power." Energies 14, no. 15: 4540.

Journal article
Published: 24 July 2021 in Energies
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The European Union considers that offshore wind power will play a key role in making the EU the first climate-neutral continent by 2050. Currently, the potential of offshore wind energy is still untapped in Spain. Furthermore, the characteristics of the coastline in Spain require floating technology, making it challenging to install wind farms due to their current high cost. This work seeks to quantify the impact that Spanish offshore wind energy would have on the Iberian electricity market. Several offshore wind scenarios are evaluated by combining available information in relation to areas suitable for installing wind farms and wind resource data. The impact on the day-ahead electricity market has been obtained by reproducing the market, including these new offshore wind generation scenarios. The introduction of this renewable energy results in a market cost reduction in what is known as the merit-order effect. According to our estimates, for each MWh of offshore wind energy introduced in the market, there would be a market cost reduction of 45 €. These savings can serve as a reference for regulators to adjust their policy framework to boost floating wind offshore generation.

ACS Style

Juan-Manuel Roldan-Fernandez; Javier Serrano-Gonzalez; Francisco Gonzalez-Longatt; Manuel Burgos-Payan. Impact of Spanish Offshore Wind Generation in the Iberian Electricity Market: Potential Savings and Policy Implications. Energies 2021, 14, 4481 .

AMA Style

Juan-Manuel Roldan-Fernandez, Javier Serrano-Gonzalez, Francisco Gonzalez-Longatt, Manuel Burgos-Payan. Impact of Spanish Offshore Wind Generation in the Iberian Electricity Market: Potential Savings and Policy Implications. Energies. 2021; 14 (15):4481.

Chicago/Turabian Style

Juan-Manuel Roldan-Fernandez; Javier Serrano-Gonzalez; Francisco Gonzalez-Longatt; Manuel Burgos-Payan. 2021. "Impact of Spanish Offshore Wind Generation in the Iberian Electricity Market: Potential Savings and Policy Implications." Energies 14, no. 15: 4481.

Review
Published: 11 July 2021 in Energies
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Stable power supply has become a crucial thing in the current era of technology and automation. Although the power system has multiple stability issues and causes, frequency fluctuation plays a vital role in normal operation, whereby a system with significant frequency deviation can lead to the needless blackouts of the whole power system. With the rapid growth in power electronic converter (PEC)-based technologies and the huge penetration of nonsynchronous generators, the modern power system is becoming more complex by the day. This paper provides a comprehensive study on the stability issues that occur in modern power systems, mainly due to PEC-based technology integration. The in-depth reasons and the impacts of unstable power systems, along with their controlling techniques, are discussed to generate a clear understanding. Furthermore, the importance of frequency stability in a power system is discussed with respect to some important events that occurred in the past. This paper also discusses some potential techniques that could be performed to overcome the existing and/or upcoming challenges in the upgrading power system.

ACS Style

Ashish Shrestha; Francisco Gonzalez-Longatt. Frequency Stability Issues and Research Opportunities in Converter Dominated Power System. Energies 2021, 14, 4184 .

AMA Style

Ashish Shrestha, Francisco Gonzalez-Longatt. Frequency Stability Issues and Research Opportunities in Converter Dominated Power System. Energies. 2021; 14 (14):4184.

Chicago/Turabian Style

Ashish Shrestha; Francisco Gonzalez-Longatt. 2021. "Frequency Stability Issues and Research Opportunities in Converter Dominated Power System." Energies 14, no. 14: 4184.

Journal article
Published: 04 June 2021 in Energies
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Withthe massive penetration of electronic power converter (EPC)-based technologies, numerous issues are being noticed in the modern power system that may directly affect system dynamics and operational security. The estimation of system performance parameters is especially important for transmission system operators (TSOs) in order to operate a power system securely. This paper presents a Bayesian model to forecast short-term kinetic energy time series data for a power system, which can thus help TSOs to operate a respective power system securely. A Markov chain Monte Carlo (MCMC) method used as a No-U-Turn sampler and Stan’s limited-memory Broyden–Fletcher–Goldfarb–Shanno (LM-BFGS) algorithm is used as the optimization method here. The concept of decomposable time series modeling is adopted to analyze the seasonal characteristics of datasets, and numerous performance measurement matrices are used for model validation. Besides, an autoregressive integrated moving average (ARIMA) model is used to compare the results of the presented model. At last, the optimal size of the training dataset is identified, which is required to forecast the 30-min values of the kinetic energy with a low error. In this study, one-year univariate data (1-min resolution) for the integrated Nordic power system (INPS) are used to forecast the kinetic energy for sequences of 30 min (i.e., short-term sequences). Performance evaluation metrics such as the root-mean-square error (RMSE), mean absolute error (MAE), mean absolute percentage error (MAPE), and mean absolute scaled error (MASE) of the proposed model are calculated here to be 4.67, 3.865, 0.048, and 8.15, respectively. In addition, the performance matrices can be improved by up to 3.28, 2.67, 0.034, and 5.62, respectively, by increasing MCMC sampling. Similarly, 180.5 h of historic data is sufficient to forecast short-term results for the case study here with an accuracy of 1.54504 for the RMSE.

ACS Style

Ashish Shrestha; Bishal Ghimire; Francisco Gonzalez-Longatt. A Bayesian Model to Forecast the Time Series Kinetic Energy Data for a Power System. Energies 2021, 14, 3299 .

AMA Style

Ashish Shrestha, Bishal Ghimire, Francisco Gonzalez-Longatt. A Bayesian Model to Forecast the Time Series Kinetic Energy Data for a Power System. Energies. 2021; 14 (11):3299.

Chicago/Turabian Style

Ashish Shrestha; Bishal Ghimire; Francisco Gonzalez-Longatt. 2021. "A Bayesian Model to Forecast the Time Series Kinetic Energy Data for a Power System." Energies 14, no. 11: 3299.

Journal article
Published: 22 March 2021 in Electronics
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Accompanying the advancement on the Internet of Things (IoT), the concept of remote monitoring and control using IoT devices is becoming popular. Digital smart meters hold many advantages over traditional analog meters, and smart metering is one of application of IoT technology. It supports the conventional power system in adopting modern concepts like smart grids, block-chains, automation, etc. due to their remote load monitoring and control capabilities. However, in many applications, the traditional analog meters still are preferred over digital smart meters due to the high deployment and operating costs, and the unreliability of the smart meters. The primary reasons behind these issues are a lack of a reliable and affordable communication system, which can be addressed by the deployment of a dedicated network formed with a Low Power Wide Area (LPWA) platform like wireless radio standards (i.e., LoRa devices). This paper discusses LoRa technology and its implementation to solve the problems associated with smart metering, especially considering the rural energy system. A simulation-based study has been done to analyse the LoRa technology’s applicability in different architecture for smart metering purposes and to identify a cost-effective and reliable way to implement smart metering, especially in a rural microgrid (MG).

ACS Style

Anup Marahatta; Yaju Rajbhandari; Ashish Shrestha; Ajay Singh; Anup Thapa; Francisco Gonzalez-Longatt; Petr Korba; Seokjoo Shin. Evaluation of a LoRa Mesh Network for Smart Metering in Rural Locations. Electronics 2021, 10, 751 .

AMA Style

Anup Marahatta, Yaju Rajbhandari, Ashish Shrestha, Ajay Singh, Anup Thapa, Francisco Gonzalez-Longatt, Petr Korba, Seokjoo Shin. Evaluation of a LoRa Mesh Network for Smart Metering in Rural Locations. Electronics. 2021; 10 (6):751.

Chicago/Turabian Style

Anup Marahatta; Yaju Rajbhandari; Ashish Shrestha; Ajay Singh; Anup Thapa; Francisco Gonzalez-Longatt; Petr Korba; Seokjoo Shin. 2021. "Evaluation of a LoRa Mesh Network for Smart Metering in Rural Locations." Electronics 10, no. 6: 751.

Journal article
Published: 25 February 2021 in Energies
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The replacement of conventional generation sources by DER creates the need to carefully manage the reactive power maintaining the power system safe operation. The principal trend is to increase the DER volume connected to the distribution network in the coming years. Therefore, the microgrid represents an alternative to offer reactive power management due to excellent controllability features embedded in the DER, which enable effective interaction between the microgrid and the distribution network. This paper proposes a microgrid–iterative reactive power management approach of power-electronic converter based renewable technologies for day-ahead operation. It is designed to be a centralised control based on local measurements, which provides the optimal reactive power dispatch and minimise the total energy losses inside the microgrid and maintain the voltage profile within operational limits. The proposed optimal-centralised control is contrasted against seven local reactive power controls using a techno-economic approach considering the steady–state voltage profile, the energy losses, and the reactive power costs as performance metrics. Three different reactive power pricing are proposed. The numerical results demonstrate the optimal microgrid–interactive reactive power management is the most suitable techno-economic reactive power control for the day–ahead operation.

ACS Style

Martha Acosta; Francisco Gonzalez-Longatt; Danijel Topić; Manuel Andrade. Optimal Microgrid–Interactive Reactive Power Management for Day–Ahead Operation. Energies 2021, 14, 1275 .

AMA Style

Martha Acosta, Francisco Gonzalez-Longatt, Danijel Topić, Manuel Andrade. Optimal Microgrid–Interactive Reactive Power Management for Day–Ahead Operation. Energies. 2021; 14 (5):1275.

Chicago/Turabian Style

Martha Acosta; Francisco Gonzalez-Longatt; Danijel Topić; Manuel Andrade. 2021. "Optimal Microgrid–Interactive Reactive Power Management for Day–Ahead Operation." Energies 14, no. 5: 1275.

Journal article
Published: 12 January 2021 in Electronics
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Frequency in power systems is a real-time information that shows the balance between generation and demand. Good system frequency observation is vital for system security and protection. This paper analyses the system frequency response following disturbances and proposes a data-driven approach for predicting it by using machine learning techniques like Nonlinear Auto-regressive (NAR) Neural Networks (NN) and Long Short Term Memory (LSTM) networks from simulated and measured Phasor Measurement Unit (PMU) data. The proposed method uses a horizon-window that reconstructs the frequency input time-series data in order to predict the frequency features such as Nadir. Simulated scenarios are based on the gradual inertia reduction by including non-synchronous generation into the Nordic 32 test system, whereas the PMU collected data is taken from different locations in the Nordic Power System (NPS). Several horizon-windows are experimented in order to observe an adequate margin of prediction. Scenarios considering noisy signals are also evaluated in order to provide a robustness index of predictability. Results show the proper performance of the method and the adequate level of prediction based on the Root Mean Squared Error (RMSE) index.

ACS Style

Harold R. Chamorro; Alvaro D. Orjuela-Cañón; David Ganger; Mattias Persson; Francisco Gonzalez-Longatt; Lazaro Alvarado-Barrios; Vijay K. Sood; Wilmar Martinez. Data-Driven Trajectory Prediction of Grid Power Frequency Based on Neural Models. Electronics 2021, 10, 151 .

AMA Style

Harold R. Chamorro, Alvaro D. Orjuela-Cañón, David Ganger, Mattias Persson, Francisco Gonzalez-Longatt, Lazaro Alvarado-Barrios, Vijay K. Sood, Wilmar Martinez. Data-Driven Trajectory Prediction of Grid Power Frequency Based on Neural Models. Electronics. 2021; 10 (2):151.

Chicago/Turabian Style

Harold R. Chamorro; Alvaro D. Orjuela-Cañón; David Ganger; Mattias Persson; Francisco Gonzalez-Longatt; Lazaro Alvarado-Barrios; Vijay K. Sood; Wilmar Martinez. 2021. "Data-Driven Trajectory Prediction of Grid Power Frequency Based on Neural Models." Electronics 10, no. 2: 151.

Journal article
Published: 08 December 2020 in Energies
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The increasing deployment of wind power is reducing inertia in power systems. High-voltage direct current (HVDC) technology can help to improve the stability of AC areas in which a frequency response is required. Moreover, multi-terminal DC (MTDC) networks can be optimized to distribute active power to several AC areas by droop control setting schemes that adjust converter control parameters. To this end, in this paper, particle swarm optimization (PSO) is used to improve the primary frequency response in AC areas considering several grid limitations and constraints. The frequency control uses an optimization process that minimizes the frequency nadir and the settling time in the primary frequency response. Secondly, another layer is proposed for the redistribution of active power among several AC areas, if required, without reserving wind power capacity. This method takes advantage of the MTDC topology and considers the grid code limitations at the same time. Two scenarios are defined to provide grid code-compliant frequency control.

ACS Style

Melanie Hoffmann; Harold R. Chamorro; Marc René Lotz; José M. Maestre; Kumars Rouzbehi; Francisco Gonzalez-Longatt; Michael Kurrat; Lazaro Alvarado-Barrios; Vijay K. Sood. Grid Code-Dependent Frequency Control Optimization in Multi-Terminal DC Networks. Energies 2020, 13, 6485 .

AMA Style

Melanie Hoffmann, Harold R. Chamorro, Marc René Lotz, José M. Maestre, Kumars Rouzbehi, Francisco Gonzalez-Longatt, Michael Kurrat, Lazaro Alvarado-Barrios, Vijay K. Sood. Grid Code-Dependent Frequency Control Optimization in Multi-Terminal DC Networks. Energies. 2020; 13 (24):6485.

Chicago/Turabian Style

Melanie Hoffmann; Harold R. Chamorro; Marc René Lotz; José M. Maestre; Kumars Rouzbehi; Francisco Gonzalez-Longatt; Michael Kurrat; Lazaro Alvarado-Barrios; Vijay K. Sood. 2020. "Grid Code-Dependent Frequency Control Optimization in Multi-Terminal DC Networks." Energies 13, no. 24: 6485.

Chapter
Published: 03 November 2020 in Numerical Methods for Energy Applications
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The transition to a low-carbon society is the driving force pushing the traditional power system to increase the volume of non-synchronous technologies which mainly use power electronic converters (PEC) as an interface to the power network. Today, PEC is found in many applications ranging from generation, transmission, storage, and even active loads and protections. The variety of types, applications is almost unlimited. However, the behaviour of PEC is radically different to the typical devices used in traditional power systems, and its specificity in terms of control, overload characteristics, etc. entails an entirely different approach for modelling and simulation. This chapter presents a general review of the main concepts related to power electronic converters and their implementation in DIgSILNET PowerFactory. The chapter finalises with a discussion about the modern tendencies in power electronic applications in power systems: grid following and grid-forming converters.

ACS Style

Francisco M. Gonzalez-Longatt; Martha Nohemi Acosta; Harold R. Chamorro; José Luis Rueda Torres. Power Converters Dominated Power Systems. Numerical Methods for Energy Applications 2020, 1 -35.

AMA Style

Francisco M. Gonzalez-Longatt, Martha Nohemi Acosta, Harold R. Chamorro, José Luis Rueda Torres. Power Converters Dominated Power Systems. Numerical Methods for Energy Applications. 2020; ():1-35.

Chicago/Turabian Style

Francisco M. Gonzalez-Longatt; Martha Nohemi Acosta; Harold R. Chamorro; José Luis Rueda Torres. 2020. "Power Converters Dominated Power Systems." Numerical Methods for Energy Applications , no. : 1-35.

Journal article
Published: 28 October 2020 in IEEE Access
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This article proposes a new approach to the operation of unbalanced Active Distribution Systems (ADS) using an economic dispatch optimisation model for Active Distribution Systems Management (ADSM). The model proposes a two-level control strategy. The first one poses an optimisation problem with the objective of minimising total active power losses in the ADS and the second one proposes an algorithm that controls the position of the taps of three-phase on-load tap-changer (OLTC) transformers to ensure compliance with the technical constraints imposed by the Distribution System Operator (DSO). The optimisation problem is solved by MATLAB Ⓡ and DIgSILENT PowerFactory Ⓡ for power systems static simulations. This paper includes a novel peer to peer communication framework between MATLAB Ⓡ /DIgSILENT Ⓡ . The control and optimisation strategy is validated on the IEEE 34-Node Distribution Test Feeder. This network incorporates balanced and unbalanced three-phase loads, single-phase loads in the different phases, and two-phase loads. In this scientific paper, photovoltaic (PV) and wind power generation (WT) have been integrated to test feeder operation, with the support of battery energy storage systems (BESS). The correct operation of the proposed ADSM is demonstrated using numerical simulation on five scenarios considering several configurations of the renewable generation units and the batteries. The strategy has also been validated in a more extensive distribution network, proving its good performance.

ACS Style

Lazaro Alvarado-Barrios; Cesar Alvarez-Arroyo; Juan Manuel Escano; Francisco M. Gonzalez-Longatt; Jose Luis Martinez-Ramos. Two-level optimisation and control strategy for Unbalanced Active Distribution Systems Management. IEEE Access 2020, 8, 1 -1.

AMA Style

Lazaro Alvarado-Barrios, Cesar Alvarez-Arroyo, Juan Manuel Escano, Francisco M. Gonzalez-Longatt, Jose Luis Martinez-Ramos. Two-level optimisation and control strategy for Unbalanced Active Distribution Systems Management. IEEE Access. 2020; 8 ():1-1.

Chicago/Turabian Style

Lazaro Alvarado-Barrios; Cesar Alvarez-Arroyo; Juan Manuel Escano; Francisco M. Gonzalez-Longatt; Jose Luis Martinez-Ramos. 2020. "Two-level optimisation and control strategy for Unbalanced Active Distribution Systems Management." IEEE Access 8, no. : 1-1.

Journal article
Published: 15 October 2020 in Energies
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The Altai-Uliastai regional power system (AURPS) is a regional power system radially interconnected to the power system of Mongolia. The 110 kV interconnection is exceptionally long and susceptible to frequent trips because of weather conditions. The load-rich and low-inertia AURPS must be islanded during interconnection outages, and the under-frequency load shedding (UFLS) scheme must act to ensure secure operation. Traditional UFLS over-sheds local demand, negatively affecting the local population, especially during the cold Mongolian winter season. This research paper proposes a novel methodology to optimally calculate the settings of the UFLS scheme, where each parameter of the scheme is individually adjusted to minimise the total amount of disconnected load. This paper presents a computationally efficient methodology that is illustrated in a specially created co-simulation environment (DIgSILENT® PowerFactoryTM + Python). The results demonstrate an outstanding performance of the proposed approach when compared with the traditional one.

ACS Style

Martha N. Acosta; Choidorj Adiyabazar; Francisco Gonzalez-Longatt; Manuel A. Andrade; José Rueda Torres; Ernesto Vazquez; Jesús Manuel Riquelme Santos. Optimal Under-Frequency Load Shedding Setting at Altai-Uliastai Regional Power System, Mongolia. Energies 2020, 13, 5390 .

AMA Style

Martha N. Acosta, Choidorj Adiyabazar, Francisco Gonzalez-Longatt, Manuel A. Andrade, José Rueda Torres, Ernesto Vazquez, Jesús Manuel Riquelme Santos. Optimal Under-Frequency Load Shedding Setting at Altai-Uliastai Regional Power System, Mongolia. Energies. 2020; 13 (20):5390.

Chicago/Turabian Style

Martha N. Acosta; Choidorj Adiyabazar; Francisco Gonzalez-Longatt; Manuel A. Andrade; José Rueda Torres; Ernesto Vazquez; Jesús Manuel Riquelme Santos. 2020. "Optimal Under-Frequency Load Shedding Setting at Altai-Uliastai Regional Power System, Mongolia." Energies 13, no. 20: 5390.

Journal article
Published: 14 August 2020 in Energies
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The decommissioning of synchronous generators, and their replacement by decoupled renewable power plants, has a significant impact on the transient stability performance of a power system. This paper concerns with an investigation of the degree of transient stability enhancement that can be achieved in power systems with high shares (e.g., around 75%) of wind generation. It is considered that the wind generators can work either under the principle of current control or under the principle of fast local voltage control. In both cases, a power–angle modulation (PAM) controller is superimposed on the current control loops of the grid side converters of the wind generators. The investigation of the degree of enhancement takes into account different approaches of the tuning of PAM. It considers a simple approach in the form of parametric sensitivity, and also a sophisticated approach in the form of a formal optimization problem. Besides, the paper gives insight on what is a suitable objective function of the optimization problem, which entails the best performance of PAM. The whole investigation is conducted based on a synthetic model of the Great Britain (GB) system

ACS Style

Arcadio Perilla; Stelios Papadakis; Jose Luis Rueda Torres; Mart Van Der Meijden; Peter Palensky; Francisco Gonzalez-Longatt. Transient Stability Performance of Power Systems with High Share of Wind Generators Equipped with Power-Angle Modulation Controllers or Fast Local Voltage Controllers. Energies 2020, 13, 4205 .

AMA Style

Arcadio Perilla, Stelios Papadakis, Jose Luis Rueda Torres, Mart Van Der Meijden, Peter Palensky, Francisco Gonzalez-Longatt. Transient Stability Performance of Power Systems with High Share of Wind Generators Equipped with Power-Angle Modulation Controllers or Fast Local Voltage Controllers. Energies. 2020; 13 (16):4205.

Chicago/Turabian Style

Arcadio Perilla; Stelios Papadakis; Jose Luis Rueda Torres; Mart Van Der Meijden; Peter Palensky; Francisco Gonzalez-Longatt. 2020. "Transient Stability Performance of Power Systems with High Share of Wind Generators Equipped with Power-Angle Modulation Controllers or Fast Local Voltage Controllers." Energies 13, no. 16: 4205.

Journal article
Published: 20 July 2020 in IEEE Open Access Journal of Power and Energy
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This paper presents different forms of Fast Active Power Injection (FAPI) control schemes for the analysis and development of different mitigation measures to address the frequency stability problem due to the growth of the penetration level of the Power Electronic Interfaced Generation (PEIG) in sustainable interconnected energy systems. Among the studied FAPI control schemes, two different approaches in the form of a derivative-based control and a virtual synchronous power (VSP) based control for wind turbine applications are also proposed. All schemes are attached to the PEIG represented by a generic model of wind turbines type 4. The derivative-based FAPI control is applied as an extension of the droop based control scheme, which is dependent on the measurement of the network frequency. By contrast, the proposed VSP-based FAPI is fed by the measurement of the active power deviation. Additionally, unlike existing approaches for virtual synchronous machines, which are characterized by high-order transfer functions, the proposed VSP-based FAPI is defined by a second-order transfer function, which can contribute to fast mitigation of the system primary frequency deviations during containment period. The Great Britain (GB) test system, for the Gone-Green planning scenario for the year 2030 (GG2030), is used to evaluate the effects of the proposed FAPI controllers on the dynamics of the system frequency within the frequency containment period. Thanks to proposed FAPI controllers, it is possible to reach up to 70% for the share of wind power generation without violating the threshold limits for frequency stability. For verification purposes, a full-scale wind turbine facilitated with each FAPI controller is tested in EMT real-time simulation environment.

ACS Style

Elyas Rakhshani; Arcadio Perilla; Jose L. Rueda Torres; Francisco M. Gonzalez-Longatt; Thiago Batista Soeiro; Mart A. M. M. Van Der Meijden. FAPI Controller for Frequency Support in Low-Inertia Power Systems. IEEE Open Access Journal of Power and Energy 2020, 7, 276 -286.

AMA Style

Elyas Rakhshani, Arcadio Perilla, Jose L. Rueda Torres, Francisco M. Gonzalez-Longatt, Thiago Batista Soeiro, Mart A. M. M. Van Der Meijden. FAPI Controller for Frequency Support in Low-Inertia Power Systems. IEEE Open Access Journal of Power and Energy. 2020; 7 (99):276-286.

Chicago/Turabian Style

Elyas Rakhshani; Arcadio Perilla; Jose L. Rueda Torres; Francisco M. Gonzalez-Longatt; Thiago Batista Soeiro; Mart A. M. M. Van Der Meijden. 2020. "FAPI Controller for Frequency Support in Low-Inertia Power Systems." IEEE Open Access Journal of Power and Energy 7, no. 99: 276-286.

Journal article
Published: 03 July 2020 in IEEE Access
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Nepal is a Himalayan country with its 83% of its geography being composed of hills and mountains. Around 22% of the Nepalese population is not receiving electricity through the national power utility and is forced to identify alternative approaches to electrification. The Micro/Mini-Grid (MG) system is one of the promising approaches in terms of cost, reliability and performance for rural electrification, where electrification through national power utility is not techno-economically feasible. However, various issues must be identified and considered during the implementation of MGs in a rural community. In this paper, numerous technical, social and management issues are identified and discussed relating to the implementation and operation of reliable and stable MGs in the Himalayas. To our knowledge, this is the first scientific work that presents a comprehensive review of Himalayan MGs and their associated elements. This article reviews the available research articles, project documents, and Government reports on MG development, from which a clear roadmap is constructed. From the comprehensive study, it is observed that the existing MGs are not adequately designed for the specific area, considering the local resources and local information. Based on the identified issues, some practical and efficient recommendations have been made, so that future MG projects will address the possible problems during the design and implementation phase.

ACS Style

Ashish Shrestha; Yaju Rajbhandari; Nasib Khadka; Aayush Bista; Anup Marahatta; Rojesh Dahal; Jiwan Kumar Mallik; Anup Thapa; Barry Hayes; Petr Korba; Francisco M. Gonzalez Longatt; Ashish Shrestha. Status of Micro/Mini-Grid Systems in a Himalayan Nation: A Comprehensive Review. IEEE Access 2020, 8, 120983 -120998.

AMA Style

Ashish Shrestha, Yaju Rajbhandari, Nasib Khadka, Aayush Bista, Anup Marahatta, Rojesh Dahal, Jiwan Kumar Mallik, Anup Thapa, Barry Hayes, Petr Korba, Francisco M. Gonzalez Longatt, Ashish Shrestha. Status of Micro/Mini-Grid Systems in a Himalayan Nation: A Comprehensive Review. IEEE Access. 2020; 8 (99):120983-120998.

Chicago/Turabian Style

Ashish Shrestha; Yaju Rajbhandari; Nasib Khadka; Aayush Bista; Anup Marahatta; Rojesh Dahal; Jiwan Kumar Mallik; Anup Thapa; Barry Hayes; Petr Korba; Francisco M. Gonzalez Longatt; Ashish Shrestha. 2020. "Status of Micro/Mini-Grid Systems in a Himalayan Nation: A Comprehensive Review." IEEE Access 8, no. 99: 120983-120998.

Journal article
Published: 01 July 2020 in Energies
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The integration of renewable resources is quickly growing in the Nordic power system (NPS), and it has led to increasing challenges for the operation and control of the NPS. Nordic countries require that the first-generation power plants have a more flexible operation regime to overcomes power imbalances coming from fluctuations of the demand and supply. This paper assesses optimal frequency support of variable-speed hydropower plants installed in Telemark and Vestfold, Norway, considering future scenarios of NPS. The total kinetic energy of the NPS is expected to be significantly reduced in the future. This paper looks into the implementation of hydropower units with a variable-speed operation regime and battery energy storage systems (BESS), equipped with fast-active power controller (FAPC) technology, to provide fast frequency response after a system frequency disturbance. The frequency support was formulated as an optimization process; therefore, the parameter of the FAPC was optimally calculated for future scenarios of low inertia in NPS. Three main futures scenarios were developed for technology penetration in the Vestfold and Telemark area in Norway. The simulation results showed that the integration variable-speed hydropower units and BESS technologies improved the frequency response even in low-kinetic energy scenarios.

ACS Style

Martha N. Acosta; Daniel Pettersen; Francisco Gonzalez-Longatt; Jaime Peredo Argos; Manuel A. Andrade. Optimal Frequency Support of Variable-Speed Hydropower Plants at Telemark and Vestfold, Norway: Future Scenarios of Nordic Power System. Energies 2020, 13, 3377 .

AMA Style

Martha N. Acosta, Daniel Pettersen, Francisco Gonzalez-Longatt, Jaime Peredo Argos, Manuel A. Andrade. Optimal Frequency Support of Variable-Speed Hydropower Plants at Telemark and Vestfold, Norway: Future Scenarios of Nordic Power System. Energies. 2020; 13 (13):3377.

Chicago/Turabian Style

Martha N. Acosta; Daniel Pettersen; Francisco Gonzalez-Longatt; Jaime Peredo Argos; Manuel A. Andrade. 2020. "Optimal Frequency Support of Variable-Speed Hydropower Plants at Telemark and Vestfold, Norway: Future Scenarios of Nordic Power System." Energies 13, no. 13: 3377.

Journal article
Published: 19 June 2020 in Energies
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During the last few years, electric power systems have undergone a widespread shift from conventional fossil-based generation toward renewable energy-based generation. Variable speed wind generators utilizing full-scale power electronics converters are becoming the preferred technology among other types of renewable-based generation, due to the high flexibility to implement different control functions that can support the stabilization of electrical power systems. This paper presents a fundamental study on the enhancement of transient stability in electrical power systems with increasing high share (i.e., above 50%) of power electronic interfaced generation. The wind generator type IV is taken as a representative form of power electronic interfaced generation, and the goal is to investigate how to mitigate the magnitude of the first swing while enhancing the damping of rotor angle oscillations triggered by major electrical disturbances. To perform such mitigation, this paper proposes a power-angle modulation (PAM) controller to adjust the post-fault active power response of the wind generator type IV, after a large disturbance occurs in the system. Based on a small size system, the PAM concept is introduced. The study is performed upon time-domain simulations and analytical formulations of the power transfer equations. Additionally, the IEEE 9 BUS system and the test model of Great Britain’s system are used to further investigate the performance of the PAM controller in a multi-machine context, as well as to perform a comparative assessment of the effect of different fault locations, and the necessary wind generators that should be equipped with PAM controllers.

ACS Style

Arcadio Perilla; José Luis Rueda Torres; Stelios Papadakis; Elyas Rakhshani; Mart Van Der Meijden; Francisco Gonzalez-Longatt. Power-Angle Modulation Controller to Support Transient Stability of Power Systems Dominated by Power Electronic Interfaced Wind Generation. Energies 2020, 13, 3178 .

AMA Style

Arcadio Perilla, José Luis Rueda Torres, Stelios Papadakis, Elyas Rakhshani, Mart Van Der Meijden, Francisco Gonzalez-Longatt. Power-Angle Modulation Controller to Support Transient Stability of Power Systems Dominated by Power Electronic Interfaced Wind Generation. Energies. 2020; 13 (12):3178.

Chicago/Turabian Style

Arcadio Perilla; José Luis Rueda Torres; Stelios Papadakis; Elyas Rakhshani; Mart Van Der Meijden; Francisco Gonzalez-Longatt. 2020. "Power-Angle Modulation Controller to Support Transient Stability of Power Systems Dominated by Power Electronic Interfaced Wind Generation." Energies 13, no. 12: 3178.

Journal article
Published: 21 May 2020 in IEEE Transactions on Smart Grid
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The ongoing reduction of the total rotational inertia in modern power systems brings about faster frequency dynamics that must be limited to maintain a secure and economical operation. Electrical energy storage systems (EESSs) have become increasingly attractive to provide fast frequency response services due to their response times. However, proper management of their finite energy reserves is required to ensure timely and secure operation. This paper proposes a deep reinforcement learning (DRL) based controller to manage the state of charge (SOC) of a Multi-EESS (M-EESS), providing frequency response services to the power grid. The proposed DRL agent is trained using an actor-critic method called Deep Deterministic Policy Gradients (DDPG) that allows for continuous action and smoother SOC control of the M-EESS. Deep neural networks (DNNs) are used to represent the actor and critic policies. The proposed strategy comprises granting the agent a constant reward for each time step that the SOC is within a specific band of its target value combined with a substantial penalty if the SOC reaches its minimum or maximum allowable values. The proposed controller is compared to benchmark DRL methods and other control techniques, i.e., Fuzzy Logic and a traditional PID control. Simulation results show the effectiveness of the proposed approach.

ACS Style

Francisco Sanchez Gorostiza; Francisco M. Gonzalez-Longatt. Deep Reinforcement Learning-Based Controller for SOC Management of Multi-Electrical Energy Storage System. IEEE Transactions on Smart Grid 2020, 11, 5039 -5050.

AMA Style

Francisco Sanchez Gorostiza, Francisco M. Gonzalez-Longatt. Deep Reinforcement Learning-Based Controller for SOC Management of Multi-Electrical Energy Storage System. IEEE Transactions on Smart Grid. 2020; 11 (6):5039-5050.

Chicago/Turabian Style

Francisco Sanchez Gorostiza; Francisco M. Gonzalez-Longatt. 2020. "Deep Reinforcement Learning-Based Controller for SOC Management of Multi-Electrical Energy Storage System." IEEE Transactions on Smart Grid 11, no. 6: 5039-5050.