Associate Professor Surachai Chaitusaney, Ph.D.
รศ. ดร.สุรชัย ชัยทัศนีย์
Education
- Ph.D. in Electrical Engineering, University of Tokyo, Japan. 2007
- M.Sc. in Electrical Engineering, Chulalongkorn University, Thailand. 2002
- B.Eng. in Electrical Engineering, Chulalongkorn University, Thailand. 2000
Email: surachai.c@chula.ac.th
Research Interest
- Power System
- Renewable Energy Integration
- Solar PV
- Third Party Access
- Electricity Market
- Smart Grid
Research Cluster
Link to
1.
Le, N T; Asdornwised, W; Chaitusaney, S; Benjapolakul, W
Application of the mixed effects model for analysing photovoltaic datasets and interpreting into meaningful insights Journal Article
In: IET Generation, Transmission and Distribution, 2021, ISSN: 17518687, (cited By 0).
@article{Le2021,
title = {Application of the mixed effects model for analysing photovoltaic datasets and interpreting into meaningful insights},
author = {N T Le and W Asdornwised and S Chaitusaney and W Benjapolakul},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85102276868&doi=10.1049%2fgtd2.12160&partnerID=40&md5=396986630bf342b005b547783065c238},
doi = {10.1049/gtd2.12160},
issn = {17518687},
year = {2021},
date = {2021-01-01},
journal = {IET Generation, Transmission and Distribution},
publisher = {John Wiley and Sons Inc},
abstract = {Energy power studies commonly apply the analysis of variance (ANOVA) method in data analysis context to find the significant difference among many compared groups or to evaluate the impact of an influential factor. However, most of the datasets in these studies are time series data or longitudinal data, which are collected from the same object over some periods. Therefore, violating the independent assumption of ANOVA is the error commonly made. This leads to the misinterpretation of the comparison tests. In this article, this problem is solved by providing the application of mixed effects model (MEM) as a viable alternative to the ANOVA. In detail, two models based on MEM are proposed to analyse the time series data of micro-inverter PV stations located in Concord city, Massachusetts, USA. In the first scenario, the average models are implemented to compare the seasonal variation of monthly yield taking into account the effects of shading conditions and different orientations. In the second scenario, the linear regression model based on MEM is implemented to estimate and compare the decline rate in a 6-year period of PV stations. The analysis results have shown that the models based on MEM performs better than ANOVA in interpreting raw time-series dataset into meaningful insights. © 2021 The Authors. IET Generation, Transmission & Distribution published by John Wiley & Sons Ltd on behalf of The Institution of Engineering and Technology},
note = {cited By 0},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
Energy power studies commonly apply the analysis of variance (ANOVA) method in data analysis context to find the significant difference among many compared groups or to evaluate the impact of an influential factor. However, most of the datasets in these studies are time series data or longitudinal data, which are collected from the same object over some periods. Therefore, violating the independent assumption of ANOVA is the error commonly made. This leads to the misinterpretation of the comparison tests. In this article, this problem is solved by providing the application of mixed effects model (MEM) as a viable alternative to the ANOVA. In detail, two models based on MEM are proposed to analyse the time series data of micro-inverter PV stations located in Concord city, Massachusetts, USA. In the first scenario, the average models are implemented to compare the seasonal variation of monthly yield taking into account the effects of shading conditions and different orientations. In the second scenario, the linear regression model based on MEM is implemented to estimate and compare the decline rate in a 6-year period of PV stations. The analysis results have shown that the models based on MEM performs better than ANOVA in interpreting raw time-series dataset into meaningful insights. © 2021 The Authors. IET Generation, Transmission & Distribution published by John Wiley & Sons Ltd on behalf of The Institution of Engineering and Technology
2.
Chanhome, A; Chaitusaney, S
In: IET Renewable Power Generation, 2021, ISSN: 17521416, (cited By 0).
@article{Chanhome2021,
title = {Coordination between the central control unit and local control function of a photovoltaic system under the uncertainties of sunlight and three-phase unbalanced loads},
author = {A Chanhome and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85105124678&doi=10.1049%2frpg2.12144&partnerID=40&md5=9137557385908253a8e0aa5f4f9925d3},
doi = {10.1049/rpg2.12144},
issn = {17521416},
year = {2021},
date = {2021-01-01},
journal = {IET Renewable Power Generation},
publisher = {John Wiley and Sons Inc},
abstract = {At present, high penetration of photovoltaic (PV) systems on low voltage (LV) distribution systems is increasing worldwide because of several favourable conditions, such as government policies, decreasing cost of PV technologies, and environmental awareness. However, varying sunlight and three-phase unbalanced load conditions can result in voltage violation, especially an overvoltage problem, and voltage unbalanced conditions that deteriorate the power quality. Therefore, disconnection of PV systems, especially on the downstream node, can occur due to the overvoltage protection of the PV system, which results in PV owners losing revenue from selling electricity. Moreover, some electrical appliances can be damaged from voltage unbalanced conditions. To support a high PV penetration and prevent these adverse impacts, this study applies a control strategy involving coordination between the Central Control Unit (CCU) and Local Control Functions (LCFs) of PV systems. The CCU applies the Adaptive Tabu Search (ATS) technique to search for the optimal LCF parameter setting of PV systems and adjusted this weekly. The optimization problem is the maximization of real power generation from all PV systems under varying (uncertain) sunlight and three-phase unbalanced loads. MATLAB programming is used for the Newton–Raphson power flow simulation on a modified 19-node distribution system. © 2021 The Authors. IET Renewable Power Generation published by John Wiley & Sons Ltd on behalf of The Institution of Engineering and Technology},
note = {cited By 0},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
At present, high penetration of photovoltaic (PV) systems on low voltage (LV) distribution systems is increasing worldwide because of several favourable conditions, such as government policies, decreasing cost of PV technologies, and environmental awareness. However, varying sunlight and three-phase unbalanced load conditions can result in voltage violation, especially an overvoltage problem, and voltage unbalanced conditions that deteriorate the power quality. Therefore, disconnection of PV systems, especially on the downstream node, can occur due to the overvoltage protection of the PV system, which results in PV owners losing revenue from selling electricity. Moreover, some electrical appliances can be damaged from voltage unbalanced conditions. To support a high PV penetration and prevent these adverse impacts, this study applies a control strategy involving coordination between the Central Control Unit (CCU) and Local Control Functions (LCFs) of PV systems. The CCU applies the Adaptive Tabu Search (ATS) technique to search for the optimal LCF parameter setting of PV systems and adjusted this weekly. The optimization problem is the maximization of real power generation from all PV systems under varying (uncertain) sunlight and three-phase unbalanced loads. MATLAB programming is used for the Newton–Raphson power flow simulation on a modified 19-node distribution system. © 2021 The Authors. IET Renewable Power Generation published by John Wiley & Sons Ltd on behalf of The Institution of Engineering and Technology
3.
Prapanukool, C; Chaitusaney, S
A novel methodology for designing solar power purchase agreement of rooftop PVs under the behind-the-meter scheme Journal Article
In: Energy Reports, vol. 6, pp. 407-415, 2020, ISSN: 23524847, (cited By 0).
@article{Prapanukool2020a,
title = {A novel methodology for designing solar power purchase agreement of rooftop PVs under the behind-the-meter scheme},
author = {C Prapanukool and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85098872299&doi=10.1016%2fj.egyr.2020.11.221&partnerID=40&md5=06b1997d4f65c626b6487d591903ed24},
doi = {10.1016/j.egyr.2020.11.221},
issn = {23524847},
year = {2020},
date = {2020-01-01},
journal = {Energy Reports},
volume = {6},
pages = {407-415},
publisher = {Elsevier Ltd},
abstract = {With a great reduction in the cost of rooftop photovoltaic systems (PVs), many new business models of PVs and the behind-the-meter scheme (BTMS) have been launched, especially the solar power purchase agreement (SPPA). The SPPA is a model that the potential investors supply and sell the PV output power to customers with the discount rates, directly. If the excess energy supplied to the grid is allowable, the investors will get additional revenue from the reverse power. The proposed rates from the investors are practically formulated in term of the SPPA discount rates on utility's retail rate. Therefore, to convince the customers while retaining revenue of the investors, attractive and feasible SPPA discount rates should be investigated thoroughly. The proposed methodology in this paper to determine the SPPA discount rates for rooftop PVs under the SPPA and BTMS is presented. The cost optimization was developed and proposed to minimize the SPPA electricity charges while maintaining an acceptable internal rate of return (IRR). The benefit of the customers is the lower electricity charges, while the benefit of the investors is the sold power from rooftop PVs. Furthermore, with the proposed methodology, the large general service load in Thailand to assess the effect of the rate of excess energy and size of rooftop PVs. From the result, it showed that an oversized rooftop PVs will restrict the SPPA discount rates. The customers will get the higher SPPA discount rate if the rate of excess energy increases. © 2020 The Author(s)},
note = {cited By 0},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
With a great reduction in the cost of rooftop photovoltaic systems (PVs), many new business models of PVs and the behind-the-meter scheme (BTMS) have been launched, especially the solar power purchase agreement (SPPA). The SPPA is a model that the potential investors supply and sell the PV output power to customers with the discount rates, directly. If the excess energy supplied to the grid is allowable, the investors will get additional revenue from the reverse power. The proposed rates from the investors are practically formulated in term of the SPPA discount rates on utility's retail rate. Therefore, to convince the customers while retaining revenue of the investors, attractive and feasible SPPA discount rates should be investigated thoroughly. The proposed methodology in this paper to determine the SPPA discount rates for rooftop PVs under the SPPA and BTMS is presented. The cost optimization was developed and proposed to minimize the SPPA electricity charges while maintaining an acceptable internal rate of return (IRR). The benefit of the customers is the lower electricity charges, while the benefit of the investors is the sold power from rooftop PVs. Furthermore, with the proposed methodology, the large general service load in Thailand to assess the effect of the rate of excess energy and size of rooftop PVs. From the result, it showed that an oversized rooftop PVs will restrict the SPPA discount rates. The customers will get the higher SPPA discount rate if the rate of excess energy increases. © 2020 The Author(s)
4.
Wangsupphaphol, A; Chaitusaney, S
A simple levelized cost of electricity for ev charging with pv and battery energy storage system: Thailand case study Journal Article
In: International Journal of Power Electronics and Drive Systems, vol. 11, no. 4, pp. 2223-2230, 2020, ISSN: 20888694, (cited By 0).
@article{Wangsupphaphol2020,
title = {A simple levelized cost of electricity for ev charging with pv and battery energy storage system: Thailand case study},
author = {A Wangsupphaphol and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85097988170&doi=10.11591%2fIJPEDS.V11.I4.PP2223-2230&partnerID=40&md5=ad1c09c97beea1628d29a03512748d06},
doi = {10.11591/IJPEDS.V11.I4.PP2223-2230},
issn = {20888694},
year = {2020},
date = {2020-01-01},
journal = {International Journal of Power Electronics and Drive Systems},
volume = {11},
number = {4},
pages = {2223-2230},
publisher = {Institute of Advanced Engineering and Science},
abstract = {This paper proposes the calculation of the simple levelized cost of electricity of PV and battery energy storage system for supporting the investment decision of the EV hybrid charging station. The paper introduces the problems of EV charging against the grid power system. Thus, the hybrid charging for EV is suggested. The study provides an architecture of the hybrid EV charging station along with the factor impacting the EV infrastructure for acknowledgment. The cost elements of the station are presented to address the benefits of the investment. Besides, the profit is mainly from the margin of the electricity price, therefore, this study compares the electricity cost of PV and PV equipped with a battery with the commercial on-peak electricity tariff. The results show that the charging cost contributed by PV alone has the lowest amount throughout the study period year 2020 – 2030. In contrast, the hybrid charging cost contributed by PV and battery has a higher value than the on-peak tariff during 2020 – 2025 but it is lower afterward. The result supports the feasibility of charging an EV by solar power and the hybrid power system in the future. © 2020, Institute of Advanced Engineering and Science. All rights reserved.},
note = {cited By 0},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
This paper proposes the calculation of the simple levelized cost of electricity of PV and battery energy storage system for supporting the investment decision of the EV hybrid charging station. The paper introduces the problems of EV charging against the grid power system. Thus, the hybrid charging for EV is suggested. The study provides an architecture of the hybrid EV charging station along with the factor impacting the EV infrastructure for acknowledgment. The cost elements of the station are presented to address the benefits of the investment. Besides, the profit is mainly from the margin of the electricity price, therefore, this study compares the electricity cost of PV and PV equipped with a battery with the commercial on-peak electricity tariff. The results show that the charging cost contributed by PV alone has the lowest amount throughout the study period year 2020 – 2030. In contrast, the hybrid charging cost contributed by PV and battery has a higher value than the on-peak tariff during 2020 – 2025 but it is lower afterward. The result supports the feasibility of charging an EV by solar power and the hybrid power system in the future. © 2020, Institute of Advanced Engineering and Science. All rights reserved.
5.
Prapanukool, C; Chaitusaney, S
Designing solar power purchase agreement of rooftop pvs with battery energy storage systems under the behind-the-meter scheme Journal Article
In: Energies, vol. 13, no. 17, 2020, ISSN: 19961073, (cited By 0).
@article{Prapanukool2020,
title = {Designing solar power purchase agreement of rooftop pvs with battery energy storage systems under the behind-the-meter scheme},
author = {C Prapanukool and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85090880424&doi=10.3390%2fen13174438&partnerID=40&md5=e78c40651d185a07ad536cce89e6f8b7},
doi = {10.3390/en13174438},
issn = {19961073},
year = {2020},
date = {2020-01-01},
journal = {Energies},
volume = {13},
number = {17},
publisher = {MDPI AG},
abstract = {With a significant growth of rooftop photovoltaic systems (PVs) with battery energy storage systems (BESS) under the behind-the-meter scheme (BTMS), the solar power purchase agreement (SPPA) has been developed into one of the most attractive models. The SPPA is a scheme where the investors propose to directly sell electricity from rooftop PVs to the customers. The proposed rates are typically performed in terms of the discount rates on the time-of-use (TOU) tariff with demand charges. The operation modes of the BESS should also be designed in accordance with the proposed rates. Therefore, this paper proposes a methodology to design the discount rates and operation modes of the BESS which will minimize the electricity charges of the customers while maintaining the revenue of the investors under the SPPA and BTMS. The reverse power flow is considered as additional revenue to the investors. This paper also implements the proposed methodology with tariff structure in Thailand. The result showed that the installed capacity of rooftop PVs and battery capacity directly affect the discount rates and operation modes of the BESS. The rate of excess energy also has a significant impact on the discount rates but not affect the operation modes. © 2020 by the authors.},
note = {cited By 0},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
With a significant growth of rooftop photovoltaic systems (PVs) with battery energy storage systems (BESS) under the behind-the-meter scheme (BTMS), the solar power purchase agreement (SPPA) has been developed into one of the most attractive models. The SPPA is a scheme where the investors propose to directly sell electricity from rooftop PVs to the customers. The proposed rates are typically performed in terms of the discount rates on the time-of-use (TOU) tariff with demand charges. The operation modes of the BESS should also be designed in accordance with the proposed rates. Therefore, this paper proposes a methodology to design the discount rates and operation modes of the BESS which will minimize the electricity charges of the customers while maintaining the revenue of the investors under the SPPA and BTMS. The reverse power flow is considered as additional revenue to the investors. This paper also implements the proposed methodology with tariff structure in Thailand. The result showed that the installed capacity of rooftop PVs and battery capacity directly affect the discount rates and operation modes of the BESS. The rate of excess energy also has a significant impact on the discount rates but not affect the operation modes. © 2020 by the authors.
6.
Chanhome, A; Chaitusaney, S
Development of three-phase unbalanced power flow using local control of connected photovoltaic systems Journal Article
In: IEEJ Transactions on Electrical and Electronic Engineering, vol. 15, no. 6, pp. 833-843, 2020, ISSN: 19314973, (cited By 2).
@article{Chanhome2020,
title = {Development of three-phase unbalanced power flow using local control of connected photovoltaic systems},
author = {A Chanhome and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85083106466&doi=10.1002%2ftee.23125&partnerID=40&md5=b74cb76f6b1dfff7f53c9db7d36d2453},
doi = {10.1002/tee.23125},
issn = {19314973},
year = {2020},
date = {2020-01-01},
journal = {IEEJ Transactions on Electrical and Electronic Engineering},
volume = {15},
number = {6},
pages = {833-843},
publisher = {John Wiley and Sons Inc.},
abstract = {With the increased number of installations of distributed photovoltaic (PV) systems within electricity distribution systems, power flow analysis is required to handle multiple PV systems. At present, PV systems are equipped with a local control function (LCF). The conventional algorithm is then applied for power flow analysis with the LCF of each PV system, where the power output of LCF of each PV system is calculated and used in the power flow calculation. The conventional algorithm is terminated when the voltage at each iteration of the power flow algorithm is converged. However, the conventional algorithm inevitably requires a lengthy calculation. This paper proposes a power flow algorithm that applies the Newton–Raphson technique to handle multiple PV systems with an LCF for a faster calculation. The LCF is approximated to have a continuous characteristic. The developed power flow algorithm can be used for a three-phase unbalanced distribution system and its effectiveness was demonstrated in a modified 19-node distribution system. © 2020 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc. © 2020 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc.},
note = {cited By 2},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
With the increased number of installations of distributed photovoltaic (PV) systems within electricity distribution systems, power flow analysis is required to handle multiple PV systems. At present, PV systems are equipped with a local control function (LCF). The conventional algorithm is then applied for power flow analysis with the LCF of each PV system, where the power output of LCF of each PV system is calculated and used in the power flow calculation. The conventional algorithm is terminated when the voltage at each iteration of the power flow algorithm is converged. However, the conventional algorithm inevitably requires a lengthy calculation. This paper proposes a power flow algorithm that applies the Newton–Raphson technique to handle multiple PV systems with an LCF for a faster calculation. The LCF is approximated to have a continuous characteristic. The developed power flow algorithm can be used for a three-phase unbalanced distribution system and its effectiveness was demonstrated in a modified 19-node distribution system. © 2020 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc. © 2020 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc.
7.
Prapanukool, C; Chaitusaney, S
Optimal Battery Capacity for Residential Rooftop PVs With Consideration of Net-Metering Scheme Compensation Period Journal Article
In: International Journal of Renewable Energy Research, vol. 9, no. 4, pp. 1724-1732, 2019, ISSN: 13090127, (cited By 2).
@article{Prapanukool2019,
title = {Optimal Battery Capacity for Residential Rooftop PVs With Consideration of Net-Metering Scheme Compensation Period},
author = {C Prapanukool and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85084261278&partnerID=40&md5=a482a8289c46fc17c65c81789e89ddbf},
issn = {13090127},
year = {2019},
date = {2019-01-01},
journal = {International Journal of Renewable Energy Research},
volume = {9},
number = {4},
pages = {1724-1732},
publisher = {International Journal of Renewable Energy Research},
abstract = {With the significant increase of the prosumers in the world, the battery energy storage system (BESS) has become an important device to enhance the performance of renewable energy generation. By focusing on residential scale of rooftop PVs, BESS has been developed and applied in many aspects especially in terms of electricity charge saving. Many papers propose the methodology to control the operation of BESS, while many papers propose the methodology to determine the battery capacity. As for this paper, the proposed methodology will simultaneously determine the operation schedule and battery capacity of BESS for rooftop PVs under a net-metering scheme (NMS). The main objective is to maximize the net present value (NPV) of the prosumers. The battery capacity will be constrained by the period of the NMS compensation which will be effective for only one year of each electricity bill. The numerical results show that, for the TOU tariff structure without demand charge, an appropriate BESS should have CNOM, DC as high as possible to increase the revenue from BESS and have PNOM, DC as low as possible to reduce the total investment cost (TTC). Also, by considering the limit period of the NMS compensation, an appropriate battery capacity should not be higher than monthly residential load consumption. Lastly, the sensitivity analysis of electricity tariff shows that the NPV will increase proportionally by the increment of electricity price, which will reduce the break-even year of the investment. © 2019 International Journal of Renewable Energy Research.},
note = {cited By 2},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
With the significant increase of the prosumers in the world, the battery energy storage system (BESS) has become an important device to enhance the performance of renewable energy generation. By focusing on residential scale of rooftop PVs, BESS has been developed and applied in many aspects especially in terms of electricity charge saving. Many papers propose the methodology to control the operation of BESS, while many papers propose the methodology to determine the battery capacity. As for this paper, the proposed methodology will simultaneously determine the operation schedule and battery capacity of BESS for rooftop PVs under a net-metering scheme (NMS). The main objective is to maximize the net present value (NPV) of the prosumers. The battery capacity will be constrained by the period of the NMS compensation which will be effective for only one year of each electricity bill. The numerical results show that, for the TOU tariff structure without demand charge, an appropriate BESS should have CNOM, DC as high as possible to increase the revenue from BESS and have PNOM, DC as low as possible to reduce the total investment cost (TTC). Also, by considering the limit period of the NMS compensation, an appropriate battery capacity should not be higher than monthly residential load consumption. Lastly, the sensitivity analysis of electricity tariff shows that the NPV will increase proportionally by the increment of electricity price, which will reduce the break-even year of the investment. © 2019 International Journal of Renewable Energy Research.
8.
Nguyen, A T; Chaitusaney, S; Yokoyama, A
Optimal strategies of siting, sizing, and scheduling of BESS: Voltage management solution for future LV network Journal Article
In: IEEJ Transactions on Electrical and Electronic Engineering, vol. 14, no. 5, pp. 694-704, 2019, ISSN: 19314973, (cited By 0).
@article{Nguyen2019a,
title = {Optimal strategies of siting, sizing, and scheduling of BESS: Voltage management solution for future LV network},
author = {A T Nguyen and S Chaitusaney and A Yokoyama},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85059954764&doi=10.1002%2ftee.22856&partnerID=40&md5=2144366469c5e04b69e6d4e15b4ecba1},
doi = {10.1002/tee.22856},
issn = {19314973},
year = {2019},
date = {2019-01-01},
journal = {IEEJ Transactions on Electrical and Electronic Engineering},
volume = {14},
number = {5},
pages = {694-704},
publisher = {John Wiley and Sons Inc.},
abstract = {With the object of reducing CO 2 emission and the reliance on fossil fuels, solar power generation has received special support and is being deployed rapidly in many distribution networks. Battery energy storage system (BESS), an effective voltage management solution for low-voltage (LV) networks to deal with the high penetration of rooftop photovoltaic (PV) systems, is investigated in this paper considering the degradation of BESS due to aging. Two optimal strategies of BESS cost minimization are proposed for long-term planning and operation planning, where the utility is the BESS owner. As for the long-term planning, a strategy for siting and sizing of BESS is formulated based on the characteristics of the network, typical load, and PV generation profiles. Then, for the operation planning, schedules of BESSs and their cost estimation are provided based on the load and PV generation forecasts of 1 day ahead. The effectiveness of the proposed methods is demonstrated on the simplified network of the Metropolitan Electricity Authority, Thailand, using MATLAB (Natick, Mssachusetts, USA) 2016a and MATPOWER 6.0. © 2019 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc. © 2019 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc.},
note = {cited By 0},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
With the object of reducing CO 2 emission and the reliance on fossil fuels, solar power generation has received special support and is being deployed rapidly in many distribution networks. Battery energy storage system (BESS), an effective voltage management solution for low-voltage (LV) networks to deal with the high penetration of rooftop photovoltaic (PV) systems, is investigated in this paper considering the degradation of BESS due to aging. Two optimal strategies of BESS cost minimization are proposed for long-term planning and operation planning, where the utility is the BESS owner. As for the long-term planning, a strategy for siting and sizing of BESS is formulated based on the characteristics of the network, typical load, and PV generation profiles. Then, for the operation planning, schedules of BESSs and their cost estimation are provided based on the load and PV generation forecasts of 1 day ahead. The effectiveness of the proposed methods is demonstrated on the simplified network of the Metropolitan Electricity Authority, Thailand, using MATLAB (Natick, Mssachusetts, USA) 2016a and MATPOWER 6.0. © 2019 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc. © 2019 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc.
9.
Chanhome, A; Chaitusaney, S
Applying control scheme function of PV inverter for minimizing voltage fluctuation and imbalance with consideration of maximum PV generation Journal Article
In: IEEJ Transactions on Electrical and Electronic Engineering, vol. 12, pp. S42-S53, 2017, ISSN: 19314973, (cited By 1).
@article{Chanhome2017,
title = {Applying control scheme function of PV inverter for minimizing voltage fluctuation and imbalance with consideration of maximum PV generation},
author = {A Chanhome and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85020258965&doi=10.1002%2ftee.22438&partnerID=40&md5=b2007cc9210d92718891ea64d1a326ba},
doi = {10.1002/tee.22438},
issn = {19314973},
year = {2017},
date = {2017-01-01},
journal = {IEEJ Transactions on Electrical and Electronic Engineering},
volume = {12},
pages = {S42-S53},
publisher = {John Wiley and Sons Inc.},
abstract = {At present, connections of photovoltaic (PV) systems to low-voltage (LV) distribution systems are growing rapidly because of the compliance with government policies, drop in the prices of PV technologies, and environmental awareness. Unfortunately, the high penetration of solar PV systems, which suffers from the intermittence of sunlight, leads to voltage fluctuation and voltage imbalance, thereby deteriorating the power quality. To cope with this problem, this paper proposes a control strategy of the PV inverter to improve the limiting and balancing of voltage profiles in an unbalanced, three-phase, four-wire LV distribution system. The control strategy is based on the real power limitation and the reactive power adjustment through a control scheme function that is embedded in all PV inverters for supporting high penetration of PV systems. However, real power limitation leads to less utilization of solar energy. Then, the concern on PV generation (real power) regarding voltage fluctuation and imbalance is optimally analyzed by multi-objective particle swarm optimization. The optimal solution of the control scheme function is numerically demonstrated in a modified 29-node LV distribution system. © 2017 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc. © 2017 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc.},
note = {cited By 1},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
At present, connections of photovoltaic (PV) systems to low-voltage (LV) distribution systems are growing rapidly because of the compliance with government policies, drop in the prices of PV technologies, and environmental awareness. Unfortunately, the high penetration of solar PV systems, which suffers from the intermittence of sunlight, leads to voltage fluctuation and voltage imbalance, thereby deteriorating the power quality. To cope with this problem, this paper proposes a control strategy of the PV inverter to improve the limiting and balancing of voltage profiles in an unbalanced, three-phase, four-wire LV distribution system. The control strategy is based on the real power limitation and the reactive power adjustment through a control scheme function that is embedded in all PV inverters for supporting high penetration of PV systems. However, real power limitation leads to less utilization of solar energy. Then, the concern on PV generation (real power) regarding voltage fluctuation and imbalance is optimally analyzed by multi-objective particle swarm optimization. The optimal solution of the control scheme function is numerically demonstrated in a modified 29-node LV distribution system. © 2017 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc. © 2017 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc.
10.
Dao, T Van; Chaitusaney, S; Hayashi, Y; Ishii, H
Optimal coordination of voltage controllable devices in distribution systems using power-based models and quadratic programming Journal Article
In: IEEJ Transactions on Electrical and Electronic Engineering, vol. 12, pp. S54-S64, 2017, ISSN: 19314973, (cited By 0).
@article{VanDao2017,
title = {Optimal coordination of voltage controllable devices in distribution systems using power-based models and quadratic programming},
author = {T Van Dao and S Chaitusaney and Y Hayashi and H Ishii},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85020284765&doi=10.1002%2ftee.22439&partnerID=40&md5=8119dc455c882cce193c5609c5b02465},
doi = {10.1002/tee.22439},
issn = {19314973},
year = {2017},
date = {2017-01-01},
journal = {IEEJ Transactions on Electrical and Electronic Engineering},
volume = {12},
pages = {S54-S64},
publisher = {John Wiley and Sons Inc.},
abstract = {The incorporation of photovoltaic (PV) inverters makes the management of voltage difficult for power system operators. One solution is to consider these inverter-based devices as controllable reactive power (VAr) sources and to coordinate them with other voltage regulating devices in the distribution system. This paper proposes some acceptable approximations to quickly formulate and solve a mixed-integer quadratic programming problem to periodically determine the optimal voltage coordination of a load tap changer, voltage regulators, capacitor banks, and PVs on a smart grid platform. The solution to the optimization problem is aided by an iteration-based algorithm. By using the MATLAB software to carry out the simulation and computation, the method is well verified by comparing its generated result with a trustworthy solution obtained from examining all possible coordinating combinations of voltage regulating devices and PVs in a modified IEEE 34-bus system. The effectiveness and features of the method are clearly illustrated on that test system by considering a time-varying load and PV generation. The obtained results demonstrate the practical application of this work to medium-voltage systems. © 2017 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc. © 2017 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc.},
note = {cited By 0},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
The incorporation of photovoltaic (PV) inverters makes the management of voltage difficult for power system operators. One solution is to consider these inverter-based devices as controllable reactive power (VAr) sources and to coordinate them with other voltage regulating devices in the distribution system. This paper proposes some acceptable approximations to quickly formulate and solve a mixed-integer quadratic programming problem to periodically determine the optimal voltage coordination of a load tap changer, voltage regulators, capacitor banks, and PVs on a smart grid platform. The solution to the optimization problem is aided by an iteration-based algorithm. By using the MATLAB software to carry out the simulation and computation, the method is well verified by comparing its generated result with a trustworthy solution obtained from examining all possible coordinating combinations of voltage regulating devices and PVs in a modified IEEE 34-bus system. The effectiveness and features of the method are clearly illustrated on that test system by considering a time-varying load and PV generation. The obtained results demonstrate the practical application of this work to medium-voltage systems. © 2017 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc. © 2017 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc.
11.
Dao, T V; Chaitusaney, S; Nguyen, H T N
Linear least-squares method for conservation voltage reduction in distribution systems with photovoltaic inverters Journal Article
In: IEEE Transactions on Smart Grid, vol. 8, no. 3, pp. 1252-1263, 2017, ISSN: 19493053, (cited By 20).
@article{Dao2017,
title = {Linear least-squares method for conservation voltage reduction in distribution systems with photovoltaic inverters},
author = {T V Dao and S Chaitusaney and H T N Nguyen},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85018269665&doi=10.1109%2fTSG.2016.2536782&partnerID=40&md5=12b807973e8108138c5c5b3a7bbb8e16},
doi = {10.1109/TSG.2016.2536782},
issn = {19493053},
year = {2017},
date = {2017-01-01},
journal = {IEEE Transactions on Smart Grid},
volume = {8},
number = {3},
pages = {1252-1263},
publisher = {Institute of Electrical and Electronics Engineers Inc.},
abstract = {Considering photovoltaic inverters (PVs) as controllable VAr sources pave the way for an effective implementation of conservation voltage reduction (CVR) in distribution systems with multiple voltage regulating devices, this paper proposes some acceptable approximations to formulate a linear least-squares problem for optimizing a CVR implementation on the smart grid platform. The optimization problem is solved by using a built-in solver of the MATLAB software embedded in an iterative-based algorithm. The proposed algorithm is well verified by comparing its generated result with a trustful solution obtained from examining all possibly coordinating combinations of voltage regulating devices and PVs in the simplified Maehongson test system in Thailand. Effectiveness of the algorithm is also illustrated on that test system with a consideration of time-variant load and PV generation. All revealed features exhibit the high ability of applying the proposed method for implementing a closed-loop CVR functionality in distribution systems. © 2016 IEEE.},
note = {cited By 20},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
Considering photovoltaic inverters (PVs) as controllable VAr sources pave the way for an effective implementation of conservation voltage reduction (CVR) in distribution systems with multiple voltage regulating devices, this paper proposes some acceptable approximations to formulate a linear least-squares problem for optimizing a CVR implementation on the smart grid platform. The optimization problem is solved by using a built-in solver of the MATLAB software embedded in an iterative-based algorithm. The proposed algorithm is well verified by comparing its generated result with a trustful solution obtained from examining all possibly coordinating combinations of voltage regulating devices and PVs in the simplified Maehongson test system in Thailand. Effectiveness of the algorithm is also illustrated on that test system with a consideration of time-variant load and PV generation. All revealed features exhibit the high ability of applying the proposed method for implementing a closed-loop CVR functionality in distribution systems. © 2016 IEEE.
12.
Chatthaworn, R; Chaitusaney, S
Robust transmission network expansion planning considering the effect of uncertain generation from renewable energy source Journal Article
In: Journal of Engineering and Applied Sciences, vol. 12, no. Specialissue6, pp. 7805-7814, 2017, ISSN: 1816949X, (cited By 1).
@article{Chatthaworn2017,
title = {Robust transmission network expansion planning considering the effect of uncertain generation from renewable energy source},
author = {R Chatthaworn and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85042157440&doi=10.3923%2fjeasci.2017.7805.7814&partnerID=40&md5=16d97fc6795394b9a67c38f168a7b497},
doi = {10.3923/jeasci.2017.7805.7814},
issn = {1816949X},
year = {2017},
date = {2017-01-01},
journal = {Journal of Engineering and Applied Sciences},
volume = {12},
number = {Specialissue6},
pages = {7805-7814},
publisher = {Medwell Journals},
abstract = {This study proposes a novel method of Robust Transmission Network Expansion Planning (RTNEP) considering effect of renewable energy generation. The RTNEP problem will be formulated by using an AC Model instead of DC Model in order to obtain more accurate result. The investment cost of transmission lines and operating cost of conventional generators are considered as the objective function of the planning. In order to obtain the robust expansion plan for all possible scenarios of renewable energy generation and loads, the method to select the suitable scenarios as the considered criteria in the planning is proposed. To obtain the optimal expansion plan, a metaheuristic algorithm called Adaptive Tabu Search (ATS) is employed in the proposed RTNEP. With the proposed method, ATS iterates between the main problem which minimizes the investment cost and operating cost and the subproblem which is the process to avoid the violation of system operating constraints by using generation re-dispatch and curtailments of renewable energy generation and loads. The IEEE Reliability Test System 79 (RTS 79) is used to test the proposed method and to study the effect of renewable energy generation on RTNEP. The results show that the proposed RTNEP provides the solution more robust than the previous works and the effect of renewable energy generation on RTNEP is rather high which cannot be neglected in the planning. © Medwell Journals, 2017.},
note = {cited By 1},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
This study proposes a novel method of Robust Transmission Network Expansion Planning (RTNEP) considering effect of renewable energy generation. The RTNEP problem will be formulated by using an AC Model instead of DC Model in order to obtain more accurate result. The investment cost of transmission lines and operating cost of conventional generators are considered as the objective function of the planning. In order to obtain the robust expansion plan for all possible scenarios of renewable energy generation and loads, the method to select the suitable scenarios as the considered criteria in the planning is proposed. To obtain the optimal expansion plan, a metaheuristic algorithm called Adaptive Tabu Search (ATS) is employed in the proposed RTNEP. With the proposed method, ATS iterates between the main problem which minimizes the investment cost and operating cost and the subproblem which is the process to avoid the violation of system operating constraints by using generation re-dispatch and curtailments of renewable energy generation and loads. The IEEE Reliability Test System 79 (RTS 79) is used to test the proposed method and to study the effect of renewable energy generation on RTNEP. The results show that the proposed RTNEP provides the solution more robust than the previous works and the effect of renewable energy generation on RTNEP is rather high which cannot be neglected in the planning. © Medwell Journals, 2017.
13.
Chatthaworn, R; Chaitusaney, S
An approach for evaluating the impact of an intermittent renewable energy source on transmission expansion planning Journal Article
In: Frontiers of Information Technology and Electronic Engineering, vol. 16, no. 10, pp. 871-882, 2015, ISSN: 20959184, (cited By 0).
@article{Chatthaworn2015,
title = {An approach for evaluating the impact of an intermittent renewable energy source on transmission expansion planning},
author = {R Chatthaworn and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-84953239880&doi=10.1631%2fFITEE.1500049&partnerID=40&md5=1ab2c4323ac51646394aed6bb058e84c},
doi = {10.1631/FITEE.1500049},
issn = {20959184},
year = {2015},
date = {2015-01-01},
journal = {Frontiers of Information Technology and Electronic Engineering},
volume = {16},
number = {10},
pages = {871-882},
publisher = {Zhejiang University},
abstract = {We propose a new robust optimization approach to evaluate the impact of an intermittent renewable energy source on transmission expansion planning (TEP). The objective function of TEP is composed of the investment cost of the transmission line and the operating cost of conventional generators. A method to select suitable scenarios representing the intermittent renewable energy generation and loads is proposed to obtain robust expansion planning for all possible scenarios. A meta-heuristic algorithm called adaptive tabu search (ATS) is employed in the proposed TEP. ATS iterates between the main problem, which minimizes the investment and operating costs, and the subproblem, which minimizes the cost of power generation from conventional generators and curtailments of renewable energy generation and loads. The subproblem is solved by nonlinear programming (NLP) based on an interior point method. Moreover, the impact of an intermittent renewable energy source on TEP was evaluated by comparing expansion planning with and without consideration of a renewable energy source. The IEEE Reliability Test System 79 (RTS 79) was used for testing the proposed method and evaluating the impact of an intermittent renewable energy source on TEP. The results show that the proposed robust optimization approach provides a more robust solution than other methods and that the impact of an intermittent renewable energy source on TEP should be considered. © 2015, Journal of Zhejiang University Science Editorial Office and Springer-Verlag Berlin Heidelberg.},
note = {cited By 0},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
We propose a new robust optimization approach to evaluate the impact of an intermittent renewable energy source on transmission expansion planning (TEP). The objective function of TEP is composed of the investment cost of the transmission line and the operating cost of conventional generators. A method to select suitable scenarios representing the intermittent renewable energy generation and loads is proposed to obtain robust expansion planning for all possible scenarios. A meta-heuristic algorithm called adaptive tabu search (ATS) is employed in the proposed TEP. ATS iterates between the main problem, which minimizes the investment and operating costs, and the subproblem, which minimizes the cost of power generation from conventional generators and curtailments of renewable energy generation and loads. The subproblem is solved by nonlinear programming (NLP) based on an interior point method. Moreover, the impact of an intermittent renewable energy source on TEP was evaluated by comparing expansion planning with and without consideration of a renewable energy source. The IEEE Reliability Test System 79 (RTS 79) was used for testing the proposed method and evaluating the impact of an intermittent renewable energy source on TEP. The results show that the proposed robust optimization approach provides a more robust solution than other methods and that the impact of an intermittent renewable energy source on TEP should be considered. © 2015, Journal of Zhejiang University Science Editorial Office and Springer-Verlag Berlin Heidelberg.
14.
Chatthaworn, R; Chaitusaney, S
Improving method of robust transmission network expansion planning considering intermittent renewable energy generation and loads Journal Article
In: IET Generation, Transmission and Distribution, vol. 9, no. 13, pp. 1621-1627, 2015, ISSN: 17518687, (cited By 23).
@article{Chatthaworn2015a,
title = {Improving method of robust transmission network expansion planning considering intermittent renewable energy generation and loads},
author = {R Chatthaworn and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-84942321912&doi=10.1049%2fiet-gtd.2015.0363&partnerID=40&md5=f26e169f902491981907a6659c012564},
doi = {10.1049/iet-gtd.2015.0363},
issn = {17518687},
year = {2015},
date = {2015-01-01},
journal = {IET Generation, Transmission and Distribution},
volume = {9},
number = {13},
pages = {1621-1627},
publisher = {Institution of Engineering and Technology},
abstract = {This study presents a novel method for robust transmission network expansion planning (RTNEP) considering intermittent renewable energy generation and loads. The investment cost of transmission line and operating cost are considered as the objective function of the planning. This study proposes to select the suitable scenarios to make the robust expansion plan for all possible scenarios based on intermittent renewable energy generation and loads data in a year. Meta-heuristic algorithm called adaptive tabu search (ATS) is employed in the proposed RTNEP. ATS iterates between the main problem, which minimises the investment cost and operation cost and the subproblem, which minimises the total power generation of conventional generators and curtailments of renewable energy generation and loads. This study uses AC load flow based on Newton-Raphson method and non-linear programming (NLP) based on interior point method for solving the main problem and the subproblem, respectively. IEEE Reliability Test System 79 (RTS 79) is used for testing the proposed method. The results show that the proposed expansion plan is more robust than the solutions from other research works. © 2015 The Institution of Engineering and Technology.},
note = {cited By 23},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
This study presents a novel method for robust transmission network expansion planning (RTNEP) considering intermittent renewable energy generation and loads. The investment cost of transmission line and operating cost are considered as the objective function of the planning. This study proposes to select the suitable scenarios to make the robust expansion plan for all possible scenarios based on intermittent renewable energy generation and loads data in a year. Meta-heuristic algorithm called adaptive tabu search (ATS) is employed in the proposed RTNEP. ATS iterates between the main problem, which minimises the investment cost and operation cost and the subproblem, which minimises the total power generation of conventional generators and curtailments of renewable energy generation and loads. This study uses AC load flow based on Newton-Raphson method and non-linear programming (NLP) based on interior point method for solving the main problem and the subproblem, respectively. IEEE Reliability Test System 79 (RTS 79) is used for testing the proposed method. The results show that the proposed expansion plan is more robust than the solutions from other research works. © 2015 The Institution of Engineering and Technology.
15.
Chatthaworn, R; Chaitusaney, S
Transmission network expansion planning considering renewable energy target with Taguchi's orthogonal array testing Journal Article
In: IEEJ Transactions on Electrical and Electronic Engineering, vol. 9, no. 6, pp. 588-599, 2014, ISSN: 19314973, (cited By 6).
@article{Chatthaworn2014a,
title = {Transmission network expansion planning considering renewable energy target with Taguchi's orthogonal array testing},
author = {R Chatthaworn and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-84907927266&doi=10.1002%2ftee.22014&partnerID=40&md5=1af8a9e7c17e0ebdd2227bbc43b6372a},
doi = {10.1002/tee.22014},
issn = {19314973},
year = {2014},
date = {2014-01-01},
journal = {IEEJ Transactions on Electrical and Electronic Engineering},
volume = {9},
number = {6},
pages = {588-599},
publisher = {John Wiley and Sons Inc},
abstract = {Nowadays, renewable energy resources are becoming more and more popular. The intermittent nature of renewable energy sources will affect transmission network expansion planning (TNEP). Consequently, this paper presents a new problem formulation and solution procedure for TNEP which can cope with the intermittent characteristics. Taguchi's orthogonal array testing (TOAT) is used to select the scenarios that represent the loads and renewable energy resource uncertainties. In this paper, a new index called the 'renewable energy leak' (REL) is proposed to evaluate the 'unutilized or leaked' renewable energy in the TNEP. For minimizing the investment cost of transmission network expansion, annual generator operation cost, and annual transmission line loss cost, the meta-heuristic adaptive Tabu search (ATS) algorithm is used, while the system operating limits including the REL index are taken into account as the optimization constraints. The proposed procedure is tested in a modified IEEE Reliability Test System 79. The results show that the proposed method is efficient and promising. © 2014 Institute of Electrical Engineers of Japan.},
note = {cited By 6},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
Nowadays, renewable energy resources are becoming more and more popular. The intermittent nature of renewable energy sources will affect transmission network expansion planning (TNEP). Consequently, this paper presents a new problem formulation and solution procedure for TNEP which can cope with the intermittent characteristics. Taguchi's orthogonal array testing (TOAT) is used to select the scenarios that represent the loads and renewable energy resource uncertainties. In this paper, a new index called the 'renewable energy leak' (REL) is proposed to evaluate the 'unutilized or leaked' renewable energy in the TNEP. For minimizing the investment cost of transmission network expansion, annual generator operation cost, and annual transmission line loss cost, the meta-heuristic adaptive Tabu search (ATS) algorithm is used, while the system operating limits including the REL index are taken into account as the optimization constraints. The proposed procedure is tested in a modified IEEE Reliability Test System 79. The results show that the proposed method is efficient and promising. © 2014 Institute of Electrical Engineers of Japan.
16.
Ausavanop, O; Chanhome, A; Chaitusaney, S
An optimal allocation of distributed generation and voltage control devices for voltage regulation considering renewable energy uncertainty Journal Article
In: IEEJ Transactions on Electrical and Electronic Engineering, vol. 9, no. S1, pp. S17-S27, 2014, ISSN: 19314973, (cited By 5).
@article{Ausavanop2014,
title = {An optimal allocation of distributed generation and voltage control devices for voltage regulation considering renewable energy uncertainty},
author = {O Ausavanop and A Chanhome and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-84939193519&doi=10.1002%2ftee.22041&partnerID=40&md5=dbcc5440d1d0d3626f7be03467c1e6ec},
doi = {10.1002/tee.22041},
issn = {19314973},
year = {2014},
date = {2014-01-01},
journal = {IEEJ Transactions on Electrical and Electronic Engineering},
volume = {9},
number = {S1},
pages = {S17-S27},
publisher = {John Wiley and Sons Inc.},
abstract = {Distributed generation (DG) may result in voltage fluctuation by changing line flow and reactive power injection, especially DG that generates power from renewable energy resources. To cope with this problem, this paper proposes an optimization process to optimally regulate the system voltage profile to lie close to the desired values by using the adaptive Tabu search (ATS) algorithm. The system voltages will be regulated by using dispatchable DG and voltage control devices, i.e. voltage regulator and capacitor. Moreover, probabilistic load flow calculation by using Monte Carlo simulation is chosen to evaluate the uncertainty of DG powered by renewable energy resources. The number of switching operations of the voltage regulator and capacitor are also accounted for in the optimization constraints, as excessive frequent switching operations can damage these devices. The optimal sizes and locations of dispatchable DGs and capacitors are considered as the optimization variables. The proposed method is demonstrated in an IEEE 34-bus distribution test system and a modified 21-bus Provincial Electricity Authority (PEA) system (Thailand). © 2014 Institute of Electrical Engineers of Japan.},
note = {cited By 5},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
Distributed generation (DG) may result in voltage fluctuation by changing line flow and reactive power injection, especially DG that generates power from renewable energy resources. To cope with this problem, this paper proposes an optimization process to optimally regulate the system voltage profile to lie close to the desired values by using the adaptive Tabu search (ATS) algorithm. The system voltages will be regulated by using dispatchable DG and voltage control devices, i.e. voltage regulator and capacitor. Moreover, probabilistic load flow calculation by using Monte Carlo simulation is chosen to evaluate the uncertainty of DG powered by renewable energy resources. The number of switching operations of the voltage regulator and capacitor are also accounted for in the optimization constraints, as excessive frequent switching operations can damage these devices. The optimal sizes and locations of dispatchable DGs and capacitors are considered as the optimization variables. The proposed method is demonstrated in an IEEE 34-bus distribution test system and a modified 21-bus Provincial Electricity Authority (PEA) system (Thailand). © 2014 Institute of Electrical Engineers of Japan.
17.
Chatthaworn, R; Chaitusaney, S
Reliability evaluation of power systems with high short-circuit current reduction Journal Article
In: IEEJ Transactions on Electrical and Electronic Engineering, vol. 9, no. 3, pp. 241-250, 2014, ISSN: 19314973, (cited By 3).
@article{Chatthaworn2014b,
title = {Reliability evaluation of power systems with high short-circuit current reduction},
author = {R Chatthaworn and S Chaitusaney},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-84899123056&doi=10.1002%2ftee.21962&partnerID=40&md5=72f1e34c31fd8a5973cab28b8eaad11a},
doi = {10.1002/tee.21962},
issn = {19314973},
year = {2014},
date = {2014-01-01},
journal = {IEEJ Transactions on Electrical and Electronic Engineering},
volume = {9},
number = {3},
pages = {241-250},
publisher = {John Wiley and Sons Inc.},
abstract = {Similar to other cities worldwide, the increasing amounts of short-circuit current in Bangkok (Thailand) and the vicinity areas are becoming higher than the interrupting capacity (IC) of circuit breakers. To cope with the problem, the Electricity Generating Authority of Thailand (EGAT) has come up with the solutions of network reconfiguration, e.g. bus splitting and transmission line disconnecting. These solutions help reduce effectively the amounts of short-circuit currents by increasing the equivalent system impedance. However, bus splitting and transmission line disconnecting tend to decrease the system reliability. One of the alternative approaches, the installation of high-voltage direct current (HVDC) can help reduce the amounts of short-circuit currents, while the system reliability is maintained. Therefore, this paper mainly presents the reliability evaluation method of the systems with HVDC installation, which requires AC/DC power flow calculation. To avoid system constraint violation, generation redispatch, load shedding, and DC power flow control are executed. The Monte Carlo simulation is used to repeatedly evaluate the system reliability until convergence. The proposed method is tested in (i) the IEEE Reliability Test System 79 (RTS79) to confirm the correctness of reliability evaluation and (ii) the system of EGAT Bangkok including its vicinity areas to show the readiness for real implementation. Comparison of reliability indices among all solutions of short-circuit current reduction is presented and discussed. The results show that the proposed method is effective and the HVDC installation can increase the system reliability, depending on its installation location and capacity. © 2014 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc.},
note = {cited By 3},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
Similar to other cities worldwide, the increasing amounts of short-circuit current in Bangkok (Thailand) and the vicinity areas are becoming higher than the interrupting capacity (IC) of circuit breakers. To cope with the problem, the Electricity Generating Authority of Thailand (EGAT) has come up with the solutions of network reconfiguration, e.g. bus splitting and transmission line disconnecting. These solutions help reduce effectively the amounts of short-circuit currents by increasing the equivalent system impedance. However, bus splitting and transmission line disconnecting tend to decrease the system reliability. One of the alternative approaches, the installation of high-voltage direct current (HVDC) can help reduce the amounts of short-circuit currents, while the system reliability is maintained. Therefore, this paper mainly presents the reliability evaluation method of the systems with HVDC installation, which requires AC/DC power flow calculation. To avoid system constraint violation, generation redispatch, load shedding, and DC power flow control are executed. The Monte Carlo simulation is used to repeatedly evaluate the system reliability until convergence. The proposed method is tested in (i) the IEEE Reliability Test System 79 (RTS79) to confirm the correctness of reliability evaluation and (ii) the system of EGAT Bangkok including its vicinity areas to show the readiness for real implementation. Comparison of reliability indices among all solutions of short-circuit current reduction is presented and discussed. The results show that the proposed method is effective and the HVDC installation can increase the system reliability, depending on its installation location and capacity. © 2014 Institute of Electrical Engineers of Japan. Published by John Wiley & Sons, Inc.
18.
Tu, D Van; Chaitusaney, S; Yokoyama, A
Maximum-allowable distributed generation considering fault ride-through requirement and reach reduction of utility relay Journal Article
In: IEEE Transactions on Power Delivery, vol. 29, no. 2, pp. 534-541, 2014, ISSN: 08858977, (cited By 20).
@article{VanTu2014,
title = {Maximum-allowable distributed generation considering fault ride-through requirement and reach reduction of utility relay},
author = {D Van Tu and S Chaitusaney and A Yokoyama},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-84897912429&doi=10.1109%2fTPWRD.2013.2279803&partnerID=40&md5=8e7ca9f325a3ff1228ad16f80ae600b3},
doi = {10.1109/TPWRD.2013.2279803},
issn = {08858977},
year = {2014},
date = {2014-01-01},
journal = {IEEE Transactions on Power Delivery},
volume = {29},
number = {2},
pages = {534-541},
publisher = {Institute of Electrical and Electronics Engineers Inc.},
abstract = {Distribution systems are changing from a one-source supplying structure into a multisource supplying structure with participations of distributed generations (DGs). These changes face problems caused by DGs. This paper considers typical problems, such as system operating limits, reach reduction of utility relay, and the fault ride-through requirement from distribution system operators (DSOs) in order to maximize DG installation. A new fault calculation technique for a system with inverter-based DGs is revised and employed in an algorithm proposed for maximizing DGs. The IEEE 34-Node Test Feeder is then used to illustrate the effectiveness of the algorithm to determine the maximum-allowable DG installed in this system. © 1986-2012 IEEE.},
note = {cited By 20},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
Distribution systems are changing from a one-source supplying structure into a multisource supplying structure with participations of distributed generations (DGs). These changes face problems caused by DGs. This paper considers typical problems, such as system operating limits, reach reduction of utility relay, and the fault ride-through requirement from distribution system operators (DSOs) in order to maximize DG installation. A new fault calculation technique for a system with inverter-based DGs is revised and employed in an algorithm proposed for maximizing DGs. The IEEE 34-Node Test Feeder is then used to illustrate the effectiveness of the algorithm to determine the maximum-allowable DG installed in this system. © 1986-2012 IEEE.
19.
Tu, D Van; Chaitusaney, S; Yokoyama, A
Fault current calculation in distribution systems with inverter-based distributed generations Journal Article
In: IEEJ Transactions on Electrical and Electronic Engineering, vol. 8, no. 5, pp. 470-477, 2013, ISSN: 19314973, (cited By 13).
@article{VanTu2013,
title = {Fault current calculation in distribution systems with inverter-based distributed generations},
author = {D Van Tu and S Chaitusaney and A Yokoyama},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-84881612773&doi=10.1002%2ftee.21882&partnerID=40&md5=44ac5610ce436b8d4cfe05235215b497},
doi = {10.1002/tee.21882},
issn = {19314973},
year = {2013},
date = {2013-01-01},
journal = {IEEJ Transactions on Electrical and Electronic Engineering},
volume = {8},
number = {5},
pages = {470-477},
publisher = {John Wiley and Sons Inc.},
abstract = {Fault current calculation in distribution systems faces the problem with participation of inverter-based distributed generation (IBDG). This paper analyzes the fault response of IBDG in order to model it under fault condition. An adaptive algorithm based on an iterative technique is then proposed to calculate the fault current in a system with the installation of IBDG. This algorithm is first validated by the conventional fault calculation technique in case of a system without IBDG. Then, a time-variant simulation is performed to validate the proposed algorithm for the system with IBDG. © 2013 Institute of Electrical Engineers of Japan.},
note = {cited By 13},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
Fault current calculation in distribution systems faces the problem with participation of inverter-based distributed generation (IBDG). This paper analyzes the fault response of IBDG in order to model it under fault condition. An adaptive algorithm based on an iterative technique is then proposed to calculate the fault current in a system with the installation of IBDG. This algorithm is first validated by the conventional fault calculation technique in case of a system without IBDG. Then, a time-variant simulation is performed to validate the proposed algorithm for the system with IBDG. © 2013 Institute of Electrical Engineers of Japan.
20.
Tu, D Van; Chaitusaney, S; Yokoyama, A
Maximization of distributed generation by considering system operating limits and protection reach reduction as constraints Journal Article
In: IEEJ Transactions on Electrical and Electronic Engineering, vol. 7, no. SUPPL. 1, pp. S37-S45, 2012, ISSN: 19314973, (cited By 4).
@article{VanTu2012,
title = {Maximization of distributed generation by considering system operating limits and protection reach reduction as constraints},
author = {D Van Tu and S Chaitusaney and A Yokoyama},
url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-84871831363&doi=10.1002%2ftee.21804&partnerID=40&md5=4fc46dcbe9e228ca961994a80ef2987d},
doi = {10.1002/tee.21804},
issn = {19314973},
year = {2012},
date = {2012-01-01},
journal = {IEEJ Transactions on Electrical and Electronic Engineering},
volume = {7},
number = {SUPPL. 1},
pages = {S37-S45},
publisher = {John Wiley and Sons Inc.},
abstract = {Increased distributed generation (DG) in systems always brings about the impacts on maintaining the operation of protection systems. This paper concentrates on the impact on the protection reach reduction and proposes a solution to eliminate this impact by using a suitable DG transformer in parallel with a grounding reactance at the neutral point of the transformer's winding. Based on this, a Tabu search algorithm is proposed to maximize DG when the system operating limits and the protection reach reduction are considered as constraints. In order to illustrate the effectiveness of this algorithm, a case study is performed through an IEEE 34 Node Test Feeder. © 2012 Institute of Electrical Engineers of Japan.},
note = {cited By 4},
keywords = {},
pubstate = {published},
tppubtype = {article}
}
Increased distributed generation (DG) in systems always brings about the impacts on maintaining the operation of protection systems. This paper concentrates on the impact on the protection reach reduction and proposes a solution to eliminate this impact by using a suitable DG transformer in parallel with a grounding reactance at the neutral point of the transformer's winding. Based on this, a Tabu search algorithm is proposed to maximize DG when the system operating limits and the protection reach reduction are considered as constraints. In order to illustrate the effectiveness of this algorithm, a case study is performed through an IEEE 34 Node Test Feeder. © 2012 Institute of Electrical Engineers of Japan.