FY2018 Study on overseas business development of Japanese high-quality energy infrastructure
Pre-Feasibility study on improvement of grid operation by introducing secure power system operation technology in Asia
Final Report
March 2019
Prepared for:
Ministry of Economy, Trade and Industry
Prerared by:
TEPCO IEC, Inc.
Bangladesh
Contents Contents ...... i Abbreviation ...... iii 1 Project Description ...... 1-1 1.1 Project Objective...... 1-1 1.2 Project Description...... 1-1 1.3 Project Implementation Structure ...... 1-3 1.4 Project Implementation Schedule ...... 1-3 2 Current Status of the Country Surveyed ...... 2-1 2.1 Basic Information about the Country ...... 2-1 Economic Conditions ...... 2-1 (1) GDP ...... 2-1 (2) Industrial Structure ...... 2-1 Economic Growth Policy ...... 2-3 2.2 Electricity Policy ...... 2-3 Overview of Electricity Sector of Bangladesh ...... 2-3 (1) Power Division ...... 2-4 (2) Power Cell ...... 2-4 (3) Bangladesh Power Development Board (BPDB)...... 2-4 (4) Bangladesh Rural Electrification Board (BREB) ...... 2-4 (5) Sustainable and Renewable Energy Development Authority (SREDA) ...... 2-5 (6) Power Grid Company of Bangladesh Ltd. (PGCB) ...... 2-5 Electricity Sector Policy ...... 2-5 Grid Code ...... 2-6 3 Current Status and Future Outlook of Electricity Supply ...... 3-1 3.1 Existing Substations, Power Stations ...... 3-1 3.2 Ongoing, Planned Substations ...... 3-10 3.3 Revisiting PSMP2016 Plan ...... 3-10 3.4 Data for Verification ...... 3-10 4 Current Status of Power Control Operation and Power Control Facilities ...... 4-1 4.1 Power Control Operation ...... 4-1 Supervisory Control System ...... 4-1 Operation ...... 4-2 (1) Supervisory Operation ...... 4-2 (2) Switching Operation ...... 4-3 (3) Data Recording ...... 4-4 (4) Voltage Regulation ...... 4-6 (5) Data Maintenance ...... 4-13 Training ...... 4-13 (1) Training Policy ...... 4-13 (2) Training Resources...... 4-13 (3) Training for operators ...... 4-14 (4) Other Programs ...... 4-14 4.2 Facilities ...... 4-14 SCADA/EMS ...... 4-14 (1) Hardware Configuration ...... 4-15 (2) Applications ...... 4-15 Communication Network ...... 4-15
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5 Issues of Power Control Operation and Control Facilities Based on Future Facility Expansion .5-1 5.1 Power Control Operation ...... 5-1 Supervisory Control System ...... 5-1 (1) Division of Roles ...... 5-1 (2) Workload ...... 5-1 Operation ...... 5-1 (1) Supervisory Operation ...... 5-1 (2) Switching Operation ...... 5-1 (3) Data Recording ...... 5-2 (4) Voltage Regulation ...... 5-2 (5) Data Maintenance ...... 5-3 Training ...... 5-3 5.2 Facilities ...... 5-3 SCADA/EMS ...... 5-3 (1) Hardware Configuration ...... 5-3 (2) Applications ...... 5-4 Communication network ...... 5-4 6 Improvements in Project Schemes ...... 6-1 6.1 Operation ...... 6-1 Supervisory Control System ...... 6-1 (1) Delegation of Authority ...... 6-1 (2) Organizational Configuration ...... 6-1 Operation ...... 6-3 (1) Supervisory Operation ...... 6-3 (2) Switching Operation ...... 6-3 (3) Data Recording ...... 6-4 (4) Voltage Regulation ...... 6-4 (5) Data Maintenance ...... 6-4 Training ...... 6-5 6.2 Facilities ...... 6-6 SCADA ...... 6-6 (1) Hardware Configuration ...... 6-6 (2) Application Configuration...... 6-6 Communication Network ...... 6-7 6.3 Project Implementation Structure and Schedule ...... 6-7 6.4 Result of Pre-Feasibility Study ...... 6-7 7 Benefits from Improvements in the Project ...... 7-1 7.1 Expected Benefits for the Partner Country ...... 7-1 Minimizing the Increase in Personnel Expenses ...... 7-1 Reductions in Economic Losses by Shortening Power Outages ...... 7-2 Reducing Loss in Leased Transmission Fees ...... 7-3 7.2 Estimating CO2 Emission Reductions ...... 7-3 7.3 Expected Benefits for Japan ...... 7-4 7.4 Assessing Japanese Companies' Competitive Advantages ...... 7-5 7.5 Possible Utilization of Financing and Government Support ...... 7-5 7.6 Promoting this Approach to Other Countries ...... 7-5
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Abbreviations ABBREVIATION FULL TYTLE ALDC Area Load Dispatching Center BLDC Bulk Load Dispatch Center BPDB Bangladesh Power Development Board BPDP Bangladesh Power Development Board BREB Bangladesh Rural Electrification Board E/O Emergency Outage EMS Energy Management System HRM Human Resource Management Department IPP Independent Power Producer MPEMR Ministry of Power, Energy and Mineral Resources NLDC National Load Dispatching Center ODA Official Development Assistance OPGW Optical Ground Wire PGCB Power Grid Company of Bangladesh Limited PLC Power Line Carrier PSMP Power System Master Plan S/O Scheduled Outage SCADA Supervisory Control And Data Acquisition SREDA Sustainable and Renewable Energy Development Authority
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1 Project Description 1.1 Project Objective Electricity Network of Bangladesh consists of only one national grid system which is wholly owned, operated and maintained by Power Grid Company of Bangladesh Ltd (PGCB). The power generation capacity of Bangladesh presently reached at about 15,000MW. Bangladesh, being a developing country, power demand is increasing rapidly. To meet up the continuously increasing demand of electricity, Government of Bangladesh (GoB) is encouraging as well as giving permission to establish new power plants both in public and private sector. . Presently, grid system of Bangladesh is running with 132kV, 230kV and 400kV transmission lines along with corresponding 132/33kV, 230/132kV, 400/230kV and 400/132kV grid substations. According to Power System Master Plan (PSMP) generation capacity of Bangladesh will reach to approximately 40,000 MW by 2030. To transmit and distribute evacuate this huge amount of generated electricity power, power grid must be expanded. Figure 1-1 shows the grid network of PGCB in 2010 and 2018.
PGCB is presently using EMS/SCADA for National Load Dispatch Center (NLDC). NLDC is monitoring and controlling (by using phone communication) all sub-stations in actual. As the reinforcement of power generation and expansion of grid, it is estimable that the current organization of NLDC will be reached to the limit. The capacity of power stations will be increased and NLDC will be involved more on generation and demand management. So, the organizational structure of NLDC should be reformed and a new setup should be established for grid monitoring and controlling. At present only 2 National Load Dispatch Centers (ALDCs) are functioning, but for the future system with large number of substations more ALDCs must be established.
This project aims to carry out a feasibility study on introduction of Japanese high-quality power system operation technology by investigating and analyzing of organization, operation and SCADA of PGCB.
1.2 Project Description This project is intended to survey the following items.
i. Background survey a. The partner country's policy trends b. The partner company's strategic trends ii. Collecting the information needed to introduce power system operation technology a. Assessing the current status of electricity infrastructure b. Assessing the partner company's needs and challenges c. Current and future trends in supervisory control systems d. Human resource development framework iii. Survey on energy-derived CO2 emission reductions a. Assessing current CO2 emissions b. Estimating CO2 emission reductions achieved by the introduction of power system operation technology iv. Checking Japanese companies' competitive advantages a. Assessing competitive advantages in power system operation
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(Source: PGCB Annual report 2009-2010) (Source: PGCB Website https://www.pgcb.org.bd/PGCB/?a=user/home.php)
Figure 1-1 Grid network of PGCB in 2010(left) and 2018(right) 1-2
1.3 Project Implementation Structure The following is the implementation structure for this project.
The responsible operator of this project is TEPCO IEC, Inc. The current status analysis and project scheme study on the cybersecurity field were conducted with the cooperation of McAfee Co., Ltd. SCADA survey and analysis were performed in collaboration with Toshiba Energy Systems & Solutions Corporation.
1.4 Project Implementation Schedule These surveys were conducted on the schedule shown in Figure 1-2.
Figure 1-2 Schedule of Pre-Feasibility Study
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2 Current Status of the Country Surveyed 2.1 Basic Information about the Country Economic Conditions (1) GDP In the past ten years, Bangladesh has been maintaining sustainable high economic growth with an average GDP growth rate of 6% or more. According to the Bangladesh Bureau of Statistics (BBS), the country's GDP growth rate increased to 7.11% in 2015-16, exceeding the level of 7% for the first time, then rose to 7.28% in 2016-17. The country’s GDP growth rates are estimated for three sectors: agriculture, industry, and service. Figure 2-1 shows the real GDP growth rates by sector.
12 [%] 10
8 7.11 7.28 6.46 6.52 6.55 6.01 6.06 5.57 6
4
2
11.09 10.22
5.62 9.67 6.15 7.03 5.53 4.46 9.02 6.22 3.01 9.44 6.58 2.46 9.64 5.51 4.37 8.16 3.33 2.79 6.25 2.97 6.69 5.8
0 2009-10 2010-11 2011-12 2012-13 2013-14 2014-15 2015-16 2016-17 Agriculture Industry Service GDP
(Source: Finance Division, Ministry of Finance, Bangladesh Economic Review 2017)
Figure 2-1 Growth of GDP by Sectors
(2) Industrial Structure The agriculture, industry, and service sectors are divided further into 15 sectors. Figure 2-2 shows the share of each of these sectors in the real GDP in 2016-17.
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Agriculture and Forestry Fishing 12% 11% Mining and Quarrying 2% 3% Manufacturing 3% 2% Electricity, Gas and Water Supply 4% Construction Wholesale and Retail Trade 8% 18% Hotel and Restaurants Transport, Storage & Communication 4% Financial Intermediations Real Estate, Renting and Business Activities 1% 10% Public Administration and Defence 8% Education 1% 13% Health and Social Works Community, Social and Personal Services
(Source: Finance Division, Ministry of Finance, Bangladesh Economic Review 2017) Figure 2-2 Sectoral Share of GDP at Constant Prices (2016-17)
Figure 2-3 shows the changes in the percentage of each sector in the GDP. Since the 1980s, the share of the service sector has remained at around 50%. This figure shows that a gradual structural change is occurring from the industry sector to the agriculture sector.
100%
90%
80%
70%
60%
50%
40%
30%
20%
10%
0% 1980-81 1985-86 1990-91 1995-96 2000-01 2005-06 2010-11 2013-14 2014-15 2015-16 2016-17
Agriculture Industry Service
(Source: Finance Division, Ministry of Finance, Bangladesh Economic Review 2017) Figure 2-3 Trend of Structural Transformation of Sectoral Shares in GDP
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Economic Growth Policy Bangladesh will celebrate the 50th Anniversary of its Independence in 2021. Under the leadership of Prime Minister Sheikh Hasina, the Government of Bangladesh adopted Vision2021 as the country's top-priority national program. In order to realize Vision2021, the General Economics Division formulated the Perspective Plan of Bangladesh (2010-2021), one of the country's most fundamental long-term plans. If Vision2021 is realized, the socioeconomic environment of Bangladesh is expected to change from a low income economy to a medium income economy. The following nine items are listed as top priority challenges of Vision2021.
Ensuring broad-based growth and reducing poverty Ensuring effective governance and sound institutions but creating a caring society Addressing globalization and regional cooperation Providing energy security for development and welfare Building a sound infrastructure and managing the urban challenge Bitigating the impacts of climate change Promoting innovation in a knowledge-based society
2.2 Electricity Policy Overview of Electricity Sector of Bangladesh In the electricity sector of Bangladesh, the Bangladesh Power Development Board (BPDB) has been consistently operating electricity generation, transmission, and distribution divisions over many years. In 1996, the BPDB started to spin off its electricity generation, transmission and distribution units one after another. Figure 2-4 shows the BPDB's current structure. Under the BPDB, there are several electricity producers including independent power producers (IPPs). In addition, there are several electricity distributors operating in each area of the country. All power grid networks are operated by the PGCB.
(Source: The Study Team) Figure 2-4 Overview of Energy Sector of Bangladesh
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The following is the overview of individual organizations.
(1) Power Division The main functions of Power Division are as follows.
All activities related to power generation, transmission and distribution; Manage all matters and policies related to the Power sector; Expand, rehabilitate and modernize power generation, transmission and distribution services in line with the increasing national demand and prepare action plans and programs accordingly; Encourage private and joint venture investment in the Power sector in addition to the government investment; Improve the standard of living of the rural poor through rural electrification and the introduction of renewable energy; Monitor revenue earnings and commercial activities of the utilities ; Promotion of renewable energy and energy efficiency through formulation of policy/regulation, different incentive mechanism and R&D.
(2) Power Cell Aiming to reform the electricity sector of Bangladesh and encourage private-sector companies to enter the electricity business, Power Cell was established in 1995 under the Ministry of Power, Energy and Mineral Resources (MPEMR).
(3) Bangladesh Power Development Board (BPDB) BPDB is mainly responsible for most of the power generation and distribution in Dhaka and the western part of Bangladesh. This Board is positioned under the Power Division of the Ministry of Power, Energy and Mineral Resources and the Government of Bangladesh. As a result of a series of reforms and reorganizations, BPDB has changed in organizational form and is now operating the following companies as its subsidiaries.
Ashuganj Power Station Company Ltd. (APSCL) Electricity Generation Company of Bangladesh (EGCB) North West Power Generation Company Ltd. (NWPGCL) West Zone Power Distribution Company Ltd. (WZPDCL)
(4) Bangladesh Rural Electrification Board (BREB) This Board was established when the Rural Electrification Board Act was enacted in 2013 replacing the Rural Electrification Board Ordinance, which was enacted in 1977. This Board was established with the aim of utilizing electricity as a means to improve the efficiency of agricultural production in rural areas.
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At present, BREB is operating 76 rural electric cooperatives called Palli Bidyuit Samity (PBS).
(5) Sustainable and Renewable Energy Development Authority (SREDA) Because its primary energy sources are gradually depleting, Bangladesh needs to ensure long- term energy security and sustainable economic growth. SREDA was established in 2012 aimed at driving the development of sustainable and renewable energy. The major roles of SREDA are described below.
Coordinate renewable energy and energy efficiency issues of the government. Promote sustainable energy. Standardize and labialize the products for RE and EE. Pilot new technologies, and take initiatives for its expansion. Create congenial environment for the investors. Research and development on RE and EE. Capacity development. Create awareness for RE and EE and Establish linkage with regional and international organizations .
(6) Power Grid Company of Bangladesh Ltd. (PGCB) PGCB was established in 1996 in the course of reorganization of the electricity sector of Bangladesh. PGCB is responsible for the operation and expansion of all power grid networks throughout the country. The Government of Bangladesh made the decision that all the country's power transmission-related assets would be transferred to PGCB from BPDP and the Dhaka Electric Supply Authority (DESA). In accordance with the government decision, PGCB took over these assets in 2002 and started transmission operations throughout the country.
Electricity Sector Policy As described in "2.1.2 Economic Growth Policy" Bangladesh formulated Vision2021 to change its socioeconomic environment to a medium income economy. In addition to Vision2021, the Government of Bangladesh announced a new growth policy called Vision2041 with the aim of becoming one of the leading industrialized countries by 2041. Today, Bangladesh depends mainly on domestically produced natural gas for energy supply. Because the supply of natural gas is expected to decrease in the future, the Government of Bangladesh formulated Power System Master Plan 2010 (PSMP2010) with the aim of diversifying energy sources on a long-term basis.
However, PSMP2010 did not progress as expected, which required a review of the plan. In order to re-look at the energy sector strategy by assessing medium- and long-term challenges and risks, the Government of Bangladesh formulated another plan called Power System Master Plan 2016 (PSMP2016). In addition, Bangladesh would not be able to become a leading industrialized country without industry sophistication, and achieving this goal would require the country to at least improve the quality of electricity supply. For this reason, the revision of PSMP included reviews of the power development plan and electricity supply plan in order to study the
2-5 possibility of improvement in the quality of electricity supply. Five viewpoints emphasized in PSMP2016 are described below.
i. Enhancement of imported energy infrastructure and its flexible operation ii. Efficient development and utilization of domestic natural resources (gas and coal) iii. Construction of a robust, high-quality power network iv. Maximization of green energy and promotion of its introduction v. Improvement of human resources and mechanisms related to the stable supply of energy
In the meanwhile, some power stations in Bangladesh are unable to generate electricity to meet specified requirements such as output and efficiency. Furthermore, some power stations are unable to even continue commercial operation as contracted for a number of reasons. Under such a situation, the supply of electricity is always lacking throughout Bangladesh, making it difficult to conduct scheduled power shut-downs for inspection. To solve these problems, the Government of Bangladesh reviewed PSMP2016 then launched "Revisiting PSMP2016" in 2018.
Grid Code ELECTRICITY GRID CODE 2012 was enacted by Bangladesh Energy Regulatory Commission at 02 January, 2012.
The Grid Code is a document that governs the boundary between the Licensee and Users and establishes procedures for operations of facilities that will use the Transmission System. It lays down both the information requirements and the procedures governing the relationship between the Licensee and Users.
Summary of Grid Code related to the grid operation and SCADA system is shown in Table 2-1. Table 2-2 describes the definition of terms which appear in boldface in Table 2-1.
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Table 2-1 Summary of Grid Code SUBJECT Details TRANSMISSION This identifies the method for data submissions by Users to the SYSTEM PLANNING Licensee for the planning and development of the Transmission System. Transmission System planning and security standards; - Voltage limits at 132 kV, 230 kV and 400 kV Bus: +/- 10% during emergencies. +/-5% during normal operations. - Line outages: single contingency of a permanent three-phase outage of any one circuit element or transformer. - Stability: to be maintained stable during a temporary fault clearance by three-phase trip within 5 cycles and followed by successful reclosure within 15 cycles. - Power factor: on 400 kV side of 400/230/132 kV substation 0.95 lagging on 230 kV side of 230/132 kV substation 0.95 lagging on 132 kV side of 132/33 kV substation 0.9 lagging CONNECTION Connection Conditions specify the technical, design and CONDITIONS operational criteria that must be complied with by any User connected to the Transmission System. OUTAGE PLANNING This describes the process by which the Licensee carries out the planning of Transmission System Outages, including interface coordination with Users. SCHEDULE AND This specifies the procedure to be adopted for the scheduling DESPATCH and dispatch of Generating Units to meet system demand. FREQUENCY AND This describes the method by which all Users of the VOLTAGE Transmission System shall cooperate with the Licensee in MANAGEMENT contributing towards effective control of the system frequency and managing the EHV voltage of the Transmission System. VOLTAGE MANAGEMENT; The NLDC and the Licensee shall jointly take appropriate measures to control Transmission System voltages that may include but not be limited to transformer tap changing and use of MVAR reserves with Generating units within technical limits agreed to between the NLDC, Licensee and Generating units. CONTINGENCY This describes the recovery process to be followed by the PLANNING Licensee and all Users in the event of Transmission System total or partial blackouts. CROSS BOUNDARY This sets down the requirements for maintaining safe working SAFETY practices associated with cross boundary operations.
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OPERATIONAL This describes the requirements for reporting, in writing, EVENT/ACCIDENT incidents that were initially reported orally by/to other Users. REPORTING REPORTABLE INCIDENTS; i. Exceptionally high/low system voltage or frequency. ii. Serious equipment problem, e.g. major circuit, transformer or bus-bar. iii. Loss of major Generating Unit. iv. Falling of Transmission line / Tower due to natural calamity. v. System split, Transmission System breakaway or Black Start. vi. Major fire incidents. vii. Major failure of protection. viii. Equipment and transmission line overload. ix. Minor equipment alarms. PROTECTION In order to safeguard a User’s system from faults that may occur on another User’s system, it is essential that certain minimum standards of protection be adopted. METERING, This specifies the minimum operational and commercial COMMUNICATION metering, communication and data acquisition requirements to ANDDATA be provided by each User at the inter-connection points and ACQUISITION also at the cross boundary circuits. DATA ACQUISITION for Transmission System; i. MW generated in each Power Station. ii. MW consumed at each Grid substation. iii. MVAR generated or absorbed in each Power Station. iv. MVAR consumed at each Grid substation. v. Voltage at all system buses. vi. Frequency in Transmission System. vii. MW & MVAR flow in each transmission line. TESTING This specifies the responsibilities and procedures for arranging and carrying out Tests which have (or may have) an effect on the Transmission System or the Generator’s or Distributor’s systems. PERFORMANCE (a) To ensure the quality of electric power in the Grid; STANDARDS FOR (b) To ensure that the Grid will be operated in a safe and TRANSMISSION efficient manner and with a high degree of reliability; and (c) (c) To specify safety standards for the protection of personnel in the work environment. (Source: Bangladesh Energy Regulatory Commission, Electricity Grid Code 2012)
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Table 2-2 Definitions Defined Term Definition Connection The technical conditions to be complied with by any User having Conditions a Connection to the Transmission System Generating Unit The combination of an alternator and a turbine set (whether steam, gas, water or wind driven) or a reciprocating engine and all of its associated equipment, which together represents a single electricity generating machine. Generator An organization that has a License to generate electricity and who is subject to the Grid Code. Licensee The holder of the Transmission License for the bulk transmission of electricity between Generators and Distributors. Outage The reduction of capacity or taking out of service of a Generating Unit, Power Station or part of the Transmission System or Distribution System Transmission System The system of EHV electric lines and electrical equipment owned and/or operated by the Licensee for the purpose of the transmission of electricity between Power Stations, External Interconnections and the Distribution System. User A person or establishment, including the Licensee, Buyer, Generator and the Supplier, who uses the Transmission System and who must comply with the provisions of the Grid Code. (Source: Bangladesh Energy Regulatory Commission, Electricity Grid Code 2012)
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3 Current Status and Future Outlook of Electricity Supply 3.1 Existing Substations, Power Stations The existing substations and power stations subject to this study are shown below by area. PGCB is managing electricity demand, etc., with its operation area divided into nine sections. As PGCB is operating not only its own substations but also other companies' substations, the following table includes other companies' facilities. Therefore, this study will be based on the use of facilities including other companies' facilities.
Table 3-1 Existing substations in Dhaka area NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 1 Ashuganj (N) 650 APSCL 400/230kV 2 Bhulta 1040 PGCB 400/230kV 3 Kaliakoir 650 PGCB 400/132kV 4 Kaliakoir 230 520 PGCB 400/230kV 5 Agargaon 600 PGCB 230/132kV 6 Aminbazar 675 PGCB 230/132kV 7 Ashuganj 300 APSCL 230/132kV 8 Ghorasal 250 BPDB 230/132kV 9 Haripur 675 PGCB 230/132kV 10 Hasnabad 675 PGCB 230/132kV 11 Maniknagar 600 PGCB 230/132kV 12 Meghnaghat Switching - PGCB 230/132kV 13 Rampura 675 PGCB 230/132kV 14 Siddhirganj 600 PGCB 230/132kV 15 Shyampur 600 PGCB 230/132kV 16 Tongi 675 PGCB 230/132kV 17 Agargaon 240 PGCB 230/132kV 18 Ashuganj 116 APSCL 132/33kV 19 Bangabhaban 70 DPDC 132/33kV 20 Bashundhara 225 DESCO 132/33kV 21 Bhasantek 240 PGCB 132/33kV 22 Bhulta 240 PGCB 132/33kV 23 BMPIL 75 Private 132/33kV 24 Dhamrai 150 PGCB 132/33kV 25 Dhanmondi 345 DPDC 132/33kV 26 Ghorasal 126 BPDB 132/33kV 27 Gulshan 240 PGCB 132/33kV 28 Haripur 240 REB 132/33kV 29 Hasnabad 300 PGCB 132/33kV 30 Joydevpur 270 PGCB 132/33kV 31 Kabirpur 360 PGCB 132/33kV 32 Kallayanpur 225 PGCB 132/33kV 33 Kamrangirchar 225 DPDC 132/33kV 34 Kodda 300 PGCB 132/33kV 35 Lalbagh 150 DPDC 132/33kV
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NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 36 Madanganj 100 DPDC 132/33kV 37 Madartek 150 DPDC 132/33kV 38 Manikganj 150 PGCB 132/33kV 39 Maniknagar 150 PGCB 132/33kV 40 Matuail 150 DPDC 132/33kV 41 MI Cement 28 Private 132/33kV 42 Mirpur 200 PGCB 132/33kV 43 Moghbazar 225 DPDC 132/33kV 44 Munshiganj 240 PGCB 132/33kV 45 Narinda 150 DPDC 132/33kV 46 Narsingdi 150 PGCB 132/33kV 47 New Tongi 240 PGCB 132/33kV 48 RSRM 25 Private 132/33kV 49 Satmasjid 240 PGCB 132/33kV 50 Savar 150 PGCB 132/33kV 51 Shyampur 300 PGCB 132/33kV 52 Siddhirganj 240 PGCB 132/33kV 53 Sitalakhya 225 DPDC 132/33kV 54 Sonargaon 150 PGCB 132/33kV 55 Tongi 225 PGCB 132/33kV 56 Ullon 150 PGCB 132/33kV 57 Uttara 3P 240 DESCO 132/33kV 58 Uttara 150 DESCO 132/33kV (Source: The Study Team)
Table 3-2 Existing substations in Chittagong area NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 1 AKSPL 380 Private 230/33kV 2 BSRM 280 Private 230/33kV 3 Hathazari 600 PGCB 230/132kV 4 Sikalbaha 300 PGCB 230/132kV 5 AKSML 80 Private 132/33kV 6 Bakulia 203 PGCB 132/33kV 7 Baroaulia 184 PGCB 132/33kV 8 Baroirhat 75 PGCB 132/33kV 9 BSRM 80 Private 132/33kV 10 Chandraghona 61 PGCB 132/33kV 11 Cox's Bazar 157 PGCB 132/33kV 12 Dohazari 150 PGCB 132/33kV 13 Halishahar 190 PGCB 132/33kV 14 Hathazari 195 PGCB 132/33kV 15 Juldah 64 PGCB 132/33kV 16 Kaptai 20 BPDB 132/33kV 17 Khagrachari 78 PGCB 132/33kV 18 Khulshi 240 PGCB 132/33kV
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NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 19 KSRM 100 Private 132/33kV 20 KYCR 20 Private 132/33kV 21 Madunaghat 82 PGCB 132/33kV 22 Matarbari 82 PGCB 132/33kV 23 MSML 30 Private 132/33kV 24 Shahmirpur 128 PGCB 132/33kV 25 Sikalbaha 116.6 BPDB 132/33kV 26 SSML 30 Private 132/33kV 27 TKCCL 75 Private 132/33kV (Source: The Study Team)
Table 3-3 Existing substations in Khulna area NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 1 Bheramara HVDC 500 PGCB HVDC 400kV 2 Bheramara 2nd HVDC 500 PGCB HVDC 400kV 3 Bheramara 450 PGCB 230/132kV 4 Khulna (S) 450 PGCB 230/132kV 5 Bagerhat 157 PGCB 132/33kV 6 Bheramara PGCB 102 PGCB 132/33kV 7 Chuadanga 150 PGCB 132/33kV 8 Faridpur 240 PGCB 132/33kV 9 Gallamari 82 PGCB 132/33kV 10 Goalpara 82 PGCB 132/33kV 11 Gopalganj 161 PGCB 132/33kV 12 Jashore 323.3 PGCB 132/33kV 13 Jhenaidah 240 PGCB 132/33kV 14 Khulna (C) 192 PGCB 132/33kV 15 Kushtia 240 PGCB 132/33kV 16 Madaripur 191 PGCB 132/33kV 17 Magura 82 PGCB 132/33kV 18 Mongla 82 PGCB 132/33kV 19 Noapara 143 PGCB 132/33kV 20 Patuakhali 191 PGCB 132/33kV 21 Satkhira 161 PGCB 132/33kV (Source: The Study Team)
Table 3-4 Existing substations in Rajshahi area NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 1 Baghabari 225 PGCB 230/132kV 2 Bogura 750 PGCB 230/132kV 3 Ishurdi 675 PGCB 230/132kV 4 Sirajganj Switching PGCB 230/132kV 5 Amnura 100 PGCB 132/33kV 6 Bogura 390 PGCB 132/33kV 7 Chapai Nawabganj 135 PGCB 132/33kV
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NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 8 Ishurdi 115 PGCB 132/33kV 9 Joypurhat 164 PGCB 132/33kV 10 Naogaon 225 PGCB 132/33kV 11 Natore 206 PGCB 132/33kV 12 Niyamatpur 141 PGCB 132/33kV 13 Pabna 150 PGCB 132/33kV 14 Rajshahi 245 PGCB 132/33kV 15 Rooppur 41 PGCB 132/33kV 16 Shahjadpur 191 PGCB 132/33kV 17 Sirajganj 207 PGCB 132/33kV (Source: The Study Team)
Table 3-5 Existing substations in Comilla area NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 1 Cumilla (N) 450 PGCB 230/132kV 2 Brahmanbaria 202 PGCB 132/33kV 3 Chandpur 150 PGCB 132/33kV 4 Chowmuhani 270 PGCB 132/33kV 5 Cumilla (N) 150 PGCB 132/33kV 6 Cumilla (S) 300 PGCB 132/33kV 7 Daudkandi 150 PGCB 132/33kV 8 Feni 195 PGCB 132/33kV 9 Ramganj 150 PGCB 132/33kV (Source: The Study Team)
Table 3-6 Existing substations in Mymensingh area NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 1 Jamalpur 232 PGCB 132/33kV 2 Kishoreganj 207.6 PGCB 132/33kV 3 Mymensingh 360 PGCB 132/33kV 4 Netrokona 157 PGCB 132/33kV 5 Sherpur 100 PGCB 132/33kV 6 Tangail 225 PGCB 132/33kV (Source: The Study Team)
Table 3-7 Existing substations in Sylhet area NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 1 Bibiyana 1040 PGCB 400/230kV 2 Fenchuganj 300 PGCB 230/132kV 3 Beanibazar 150 PGCB 132/33kV 4 Chhatak 81 PGCB 132/33kV 5 Fenchuganj 81 PGCB 132/33kV 6 Kulaura 82 PGCB 132/33kV 7 Shahjibazar 157 PGCB 132/33kV
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NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 8 Srimangal 60 PGCB 132/33kV 9 Sunamganj 78 PGCB 132/33kV 10 Sylhet 244 PGCB 132/33kV (Source: The Study Team)
Table 3-8 Existing substations in Barisal area NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 1 Barishal (N) 600 PGCB 230/132kV 2 Barishal 150 PGCB 132/33kV 3 Barishal(N) 240 PGCB 132/33kV 4 Bhandaria 82 PGCB 132/33kV 5 Bhola 60 BPDB 132/33kV (Source: The Study Team)
Table 3-9 Existing substations in Rangpur area NO. NAME CAPACITY [MVA] O&M ENTITY VOLTAGE LEVEL 1 Barapukuria 750 PGCB 230/132kV 2 Barapukuria 122 PGCB 132/33kV 3 Lalmonirhat 168 PGCB 132/33kV 4 Palashbari 197 PGCB 132/33kV 5 Panchagarh 82 PGCB 132/33kV 6 Purbasadipur 211 PGCB 132/33kV 7 Rangpur 176.6 PGCB 132/33kV 8 Saidpur 207 PGCB 132/33kV 9 Thakurgaon 750 PGCB 230/132kV (Source: The Study Team)
Table 3-10 Existing Power Stations in Dhaka area INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 1 a) Ghorasal ST Unit-1 55 40 2 b) Ghorasal ST 2 55 45 3 Ghorasal ST :Unit-3 210 170 4 Ghorashal ST Unit-4 210 180 5 Ghorashal ST Unit-5 210 190 6 Ghorashal CCPP Unit -7 365 365 7 Ghorashal Regent 108 108 8 Ghorashal 78.5MW (MAX) 78 78 9 Tongi GT 105 105 10 Horipur GT:Unit 1,2 64 40 11 Horipur NEPC (HFO) 110 110 12 Horippur Power CCPP 360 360 13 Meghnaghat CCPP 450 450 14 Shiddirganj ST 210 115
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INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 15 Horipur 412 MW CCPP 412 412 16 Siddirganj GT Unit- 1,2 210 210 17 Siddhirganj CCPP 335 MW GT 217 217 18 Siddirgonj (Desh) 100 100 19 Siddhirganj (Dutch Bangla) 100 100 20 Pagla (DPA) 50 50 21 Meghnaghat CCPP (Summit) 305 305 22 Meghnaghat IEL 100 100 23 Madanganj (Summit) 102 100 24 Madanganj-55 55 55 25 Keraniganj (Powerpac) 100 MW 100 100 26 Gagnagar (Orion) 102 102 27 Narshingdi (Doreen) 22 22 28 Summit Power (Madhbdi+ Ashulia) 80 80 29 Summit Power (Maona) 33 33 30 Summit Power, Rupgonj 33 33 31 Gazipur RPCL 52 52 32 Kodda Gazipur 149 149 33 Kathpotti 52 mw 51 51 Kamalaghat Munshigonj 34 54 54 (Banco Energy 54 MW) 35 Summit Gazipur-2 300 300 36 APR Energy, Keranigonj 300 300 37 Aggreco Bramhangoan 100 100 38 Aggrako aurahati 100 mw 100 100 39 Southern Power 55 55 40 Northen 55 MW 55 55 41 Bosila 108 CLCPC Keranigonj 108 108 (Source: BPDB Website, http://www.bpdb.gov.bd/bpdb_new/)
Table 3-11 Existing Power Stations in Chittagong area INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 1 Kaptai Hydro:Unit-1,2,3,4,5 230 230 2 Chittagong RaozanST(Gas):Unit-1 210 180 3 Chittagong RaozanST(Gas):Unit-2 210 180 4 Raozan 25MW 25 25 5 Shikalbaha ST 60 40 6 Patenga 50 MW 50 50 7 b) Shikalbaha Peaking (GT) 150 150 8 Shikalbaha 225 MW GT 225 225 9 Shikalbaha(Energis) 51 51 10 Julda 100 100 11 Dohazari Sangu 102 102
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INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 12 Hathazari 98 98 13 Barabkunda (Regent) 22 22 14 Malancha, Ctg.EPZ (United) 0 0 15 Chittagong ECPV 108 108 (Source: BPDB Website, http://www.bpdb.gov.bd/bpdb_new/)
Table 3-12 Existing Power Stations in Khulna area INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 1 Bheramara GT (Unit-1,2,3) 60 46 2 Bherama 360 MW 410 410 3 Faridpur 54 54 4 Gopalganj Peaking 109 109 5 Khulna CCPP 230 230 6 Khulna (KPCL-2) 115 115 7 Bangla Track (Noapara) 100 100 8 Noapara (khanjahan ali) 40 40 9 Bheramara HVDC Interconnector 1000 1000 (Source: BPDB Website, http://www.bpdb.gov.bd/bpdb_new/)
Table 3-13 Existing Power Stations in Rajshahi area INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 1 a)Baghabari GT 1 71 71 2 a)Baghabari GT2 100 100 3 Baghabari Peaking 52 52 4 Bera Peaking 71 71 5 Amnura 50 50 6 Chapainawabgonj 100 MW 104 104 7 Katakhali (Peaking) 50 50 8 Khtakhali (Northern) 50 50 9 Santahar Peaking 50 50 10 Sirajganj CCPP1 210 210 11 Sirajgonj CCPP 2 220 220 12 Sirajganj unit 3 141 141 13 Bogra GBB 22 22 14 Bogra(Energyprima) 20 10 15 Ullapara (Summit) 11 11 16 Rajlanka 52 MW 52 52 (Source: BPDB Website, http://www.bpdb.gov.bd/bpdb_new/)
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Table 3-14 Existing Power Stations in Comilla area INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 1 c) Ashuganj ST 3 150 135 2 Ashugonj ST 4 150 129 3 Ashugonj ST 5 150 134 4 ASHUGONJ ENGINES 53 45 5 c) Ashuganj CCPP-225MW 221 221 6 Asuganj CCPP South 360 360 7 Asugonj CCPP NORTH 360 360 8 Ashuganj (Precision) 55 55 9 d) Ashuganj (United) 53 53 10 Ashuganj (Modular) 195MW 195 195 11 Ashuganj (Midland) 51 51 12 Brahmanbaria (Agrico) (Gas) 85 85 13 Titas(Dautkandi) 52 52 14 Chandpur 163 163 15 Feni (Doreen) 22 22 16 Feni, Mahipal (Doreen) 11 11 17 Jangalia (Summit) 33 33 18 Jangalia(Lakdamavi) 52 52 19 Summit Power, Comilla 25 25 20 Daudkandi 200 MW 200 200 21 Tripura 160 160 (Source: BPDB Website, http://www.bpdb.gov.bd/bpdb_new/)
Table 3-15 Existing Power Stations in Mymensingh area INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 1 RPCL,CCPP, Mymensingh 210 202 2 Tangail (Doreen) 22 22 3 Jamalpur RPP 95 95 4 United Mymensingh PPL 200 200 5 Sarishabari Solar Plant 3 3 (Source: BPDB Website, http://www.bpdb.gov.bd/bpdb_new/)
Table 3-16 Existing Power Stations in Sylhet area INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 1 Fenchuganj CCPP-1 (Gas) 97 70 2 Fenchuganj CCPP-2(New) 104 90 3 Fenchuganj (Barakatullah) 51 51 4 Fenchuganj (Energyprima) 44 44 5 Kushiara 163 MW Fenchugonj 163 163 6 Hobiganj (Confidence-EP) 11 11 7 Shajibazar GT Unit-8, 9 70 66
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INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 8 Shahjibazar 330 MW 330 330 9 Shajibazar (Shajibazar ) 86 86 10 Shajibazar(ENERGYPRIMA) 50 50 11 Sylhet 150MW GT 142 142 12 Sylhet 20MW GT 20 20 13 Sylhet (Energyprima) 50 50 14 Sylhet(Desh) 10 10 15 Shahjahanulla 25mw 25 25 16 Summit Bibiana-2 341 341 (Source: BPDB Website, http://www.bpdb.gov.bd/bpdb_new/)
Table 3-17 Existing Power Stations in Barisal area INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 1 Barishal GT-unit-1,2 40 30 2 Summit Barisal 110MW 110 110 3 Bhola Venture 33 33 4 Bhola CCPP GT-1,2,ST 194 194 5 Bhola Agreeco 95 mw 95 95 (Source: BPDB Website, http://www.bpdb.gov.bd/bpdb_new/)
Table 3-18 Existing Power Stations in Rangpur area INSTALLED DERATED NO. NAME CAPACITY [MVA] CAPACITY [MVA] 1 Barupukuria ST 1 125 85 2 Barupukuria ST 2 125 85 3 Barapukuria ST Unit-3 274 274 4 Rangpur GT 20 20 5 Syedpur GT 20 20 (Source: BPDB Website, http://www.bpdb.gov.bd/bpdb_new/)
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3.2 Ongoing, Planned Substations PGCB has specific plans for substations to be constructed till 2023 as shown in Figure 3-1.
300 400/230 kV 400/132 kV 230/132 kV 230/33 kV 200 132/33 kV
Number 100
0 2018 2019 2020 2021 2022 2023 Year (Source: The Study Team)
Figure 3-1 Substation construction plan of PGCB until 2023
3.3 Revisiting PSMP2016 Plan Figure 3-2 shows the plans of Revisiting PSMP2016 for substations to be constructed.
500
400
765/400kV 300 400/230kV 400/132kV
Number 200 230/132kV 132/33kV 100
0 2018 2023 2028 2033 2038 Year (Source: Revisiting PSMP2016)
Figure 3-2 Year-wise the number of substations up to 2041 in Revisiting PSMP2016
3.4 Data for Verification Because near-future plans are laid out with PSMP2016 Plan modified on an as-needed basis, there are differences in the plans up to 2023 between "3.2 Ongoing, Planned Substations" and "3.3 Revisiting PSMP2016 Plan." PGCB Plan is based on a significant increase in facility expansion in preparation for a large-scale coal-fired power station whose operation is scheduled to start around 2023 and 2024. Because "3.2Ongoing, Planned Substations" is the latest plan available for the study of this project
3-10 scheme, this data will be used as base data till 2023. After 2023, this project scheme will be verified using data adjusted to eventually fit with "3.3 Revisiting PSMP2016 Plan" in 2041. Figure 3-3 shows the data for verification.
600
500
400
300 PGCB Plan
Revisiting PSMP2016 Number 200
100
0 2018 2023 2028 2033 2038 Year (Source: The Study Team)
Figure 3-3 Data used in this Pre-FS
In the meantime, studying this supervisory control organization would require data on the number of substations in each area. It is considered that the number of 230/132kV and 132/33kV substations required to supply electricity to each area is roughly proportional to the area’s electricity demand. For this reason, the total number of substations is prorated in accordance with the electricity demand in each area based on the 2041 data of Revisiting PSMP.
The number of substations in each area till 2023 is based on the respective data of "3.2 Ongoing, Planned Substations". After 2023, this project scheme will be verified using data adjusted to eventually fit with "3.3 Revisiting PSMP2016 Plan" in 2041.
Additionally, because the operation of transmission control includes the switching operation at power stations, the number of power stations is also included in this study. Some of these power stations are connected to bulk power systems and the other power stations are connected to local supply systems. These two types of power stations need to be studied separately, but there are some power stations that are connected to power systems whose voltage class is unknown. In such a case, this study assumes that power stations with a generation capacity exceeding a certain level are connected to bulk power systems.
In the meanwhile, as these plans may be revised at some points in the future, this study will be verified on the assumption of a 20% increase in the current facility expansion plan. Figure 3-4 shows the case in which the number of substations and power stations is increased by 20%. From this point forward, this study will be verified based on this data.
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300
250 Bulk Dhaka 200 Chittagong Khulna Rajshahi 150 Comilla Mymensingh
Sylhet Number 100 Barisal
50
0 2018 2023 2028 2033 2038 Year (Source: The Study Team) Figure 3-4 The case where the number of substations and power stations increased by 20%
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4 Current Status of Power Control Operation and Power Control Facilities 4.1 Power Control Operation Supervisory Control System As shown in Figure 4-1, PGCB, under the control of the Managing Director, consists mainly of four major units – Finance, Human Resource Management, Planning & Development, and Operation & Maintenance. Operation & Maintenance is divided further into three groups – Transmission-1, Transmission-2, and System Operation. Load Dispatch Team in charge of supervisory control belongs to System Operation.
(Source: The Study Team) Figure 4-1 Company Structure of PGCB
Under Load Dispatch, there are a National Load Dispatch Center (NLDC), a Backup Control Center (BCC), and three Area Load Dispatch Centers (ALDCs). As shown in Figure 4-2, NLDC is controlling power output in response to the changes in electricity consumption. NLDC is also steadily operating electric power systems depending on the amount of electricity that flows into each facility, including appropriate network configuration, voltage maintenance, and power flow management. ALDCs are conducting the routine operation of supply systems within their territory. But because NLDC has the authority to operate supply systems, ALDCs are operating under the instructions of NLDC.
Some operators reside at BCC as well so that they can respond to emergency situations until NLDC operators move in. These operators at BCC usually conduct part of NLDC operations with the aim of technical skill transfer. PGCB substations – all manned substations – are operated in close contact with NLDC and ALDCs.
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(Source: The Study Team) Figure 4-2 The monitoring and control organization of PGCB
The standard number of operators at each supervisory control center is shown in Table 4-1. These operators are working on a three-shift rotation.
Table 4-1 Standard personnel at each control center CONTROL CENTER THE NUMBER OF OPERATORS NLDC 25 ALDC 7 BACKUP CONTROL CENTER 5 SUBSTATION 8 (Source: The Study Team)
At NLDC, five crews of five operators are working on a three-shift rotation, and the division of roles between the five operators is as described below.
A supervisor who makes decisions on emergency shutdowns, etc. A person in charge of controlling electricity frequencies A person in charge of operating transmission systems A person in charge of collecting data A person in charge of reporting data At each of three ALDCs, BCC, and each substation, three crews of one or two operators are working, with no particular division of roles specified within each crew.
Operation (1) Supervisory Operation With the exception of some substations that cannot be remotely supervised, power systems are supervised by each ALDC for substations within its territory and by NLDC for other substations.
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(2) Switching Operation The work flow of switching operation for a scheduled stop operation is shown in Figure 4-3. The substation prepares a procedure in accordance with the format shown in Figure 4-4 and sends it to NLDC in advance, and NLDC confirms and approves the procedure. At the scheduled time for switching, NLDC orders the substation to conduct the switching operation. After completing the operation, the substation reports the completion of the order to NLDC. Instead of ordering the processes of switching line by line, the order for switching is given to deliver only the purpose of switching as shown in Figure 4-4. Following the order, the substation conducts the detailed processes described in the switching order form.
A substation in the territory of an ALDC conducts a switching operation after checking the details of the order among three concerned parties – the substation, the ALDC, and NLDC. Several days before the date of switching operation, NLDC prepares a procedure and stores it in SCADA. In preparing a procedure, NLDC may reuse a similar procedure prepared in the past.
(Source: The Study Team) Figure 4-3 Work flow of preparation of procedure and operation
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(Source: PGCB Web site https://www.pgcb.org.bd/PGCB/) Figure 4-4 Switching Order Form of PGCB
(3) Data Recording NLDC is collecting the following data on substations.
i) Bus (Primary & Secondary) a) Voltage ii) Transformer (Primary & Secondary) a) MW b) MVAR c) Power Factor d) Current e) TAP f) Winding Temp g) Oil Temp iii) Transmission line a) MW
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b) MVAR c) Current d) Voltage iv) Other information on outages and emergency shutdowns
The substation side writes only numerical records in log sheets every hour and reports them to NLDC or ALDC by phone. Each ALDC reports a summary of data on substations in its territory to NLDC. The need of collecting these numerical records is specified in the grid code. At the same time, similar numerical records are collected from generators. The data on generators is entered on the PGCB Intranet so that NLDC can check the data.
Assuming the number of transformers at each substation as shown in Table 4-2, the number of numerical records required for each substation is between 16 and 30. In addition to these numerical records, each ALDC reports the numerical records of transmission lines connected to substations.
Table 4-2 Number of model case logs 765/ 765/ 400/ 400/ 230/ 230/ 132/ TRANSMISSION 400KV 400KV 230KV 132KV 132KV 33KV 33KV LINE Tr×4 Tr×2 Tr×3 Tr×2 Tr×2 Tr×2 Tr×2 VOLTAGE 2 2 2 2 2 2 2 1 MW 4 2 3 2 2 2 2 1 MVAR 4 2 3 2 2 2 2 1 POWER 4 2 3 2 2 2 2 - FACTOR CURRENT 4 2 3 2 2 2 2 1 TAP 4 2 3 2 2 2 2 - WINDING 4 2 3 2 2 2 2 - TEMP OIL TEMP 4 2 3 2 2 2 2 - TOTAL 30 16 23 16 16 16 16 4 (Source: The Study Team)
The data NLDC collected will be provided to other PGCB departments. Summarized as daily reports and monthly reports along with information on outages and emergency shutdowns, the data will be made public on the PGCB webpage. In addition to key data such as electricity demand and electricity generated, these reports provide detailed information as shown in the example of a monthly report below.
i) Outage of Sub-Station equipment due to tripping/emergency maintenance ii) Outage of Transmission lines due to tripping/emergency maintenance iii) Outage of Sub-Station equipment due to schedule maintenance/project work iv) Outage of Transmission lines due to schedule maintenance/project work v) Summary of tripping and outage (Emergency / scheduled ) vi) Summary of unserved Energy
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vii) Consolidated Statement of Sub-Station performance viii) Consolidated Statement of Transmission line's performance ix) Power Interruption due to trouble in Transmission/Generation System x) Over all Power interruption report of the system xi) Maximum Load recorded at different Sub-Station xii) Area & Zone wise maximum load served during peak hour xiii) Maximum & Minimum Voltages of Grid Sub-Stations xiv) Maximum load of 230/132KV Auto transformer xv) Report on load shedding
The disclosure of this information is obligated by the government.
(4) Voltage Regulation a. Maximum Voltages Table 4-3, Table 4-4, and Table 4-5 show the records of maximum voltages at each substation from July 2017 through June 2018. The fluctuation of maximum voltages is specified in the grid code as an indicator that shows the level of power quality maintenance: within ±5% of the reference voltage in normal times and within ±10% of the reference voltage in emergency, both in all voltage classes.
In each table, the cells colored in light brown contain a maximum voltage that deviates from the reference voltage +5%, and the cells colored in dark brown contain a maximum voltage that deviates from the reference voltage +10%. One of the reasons why maximum voltages exceed the upper limit indicator is that in the northeastern regions of Bangladesh, there are a large number of generators despite their low electricity demand. In this situation, excessive reactive power tends to be generated, causing voltages to increase.
Table 4-3 MAX Voltage of 400kV Grid Sub-Station (2017-2018)
No. Name Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb. Mar. Apr. May. Jan. 1 Bibiyana 424 425 428 413 417 413 425 416 397 2 Bheramara 424 395 425 425 422 417 418 419 495 3 Kaliakoir 396 399 403 409 410 396 428 416 384 (Source: The Study Team)
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Table 4-4 MAX Voltage of 230kV Grid Sub-Station (2017-2018)
No. Name Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb. Mar. Apr. May. Jan. 1 Ghorasal 230 230 230 230 235 240 242 240 232 235 240 2 Ishurdi 236 236 240 236 241 243 242 250 237 238 243 3 Ashuganj 242 240 240 238 245 245 247 244 240 240 245 4 Serajganj 225 224 235 225 230 231 232 248 234 232 231 5 Baghabari 228 227 235 230 232 237 232 253 239 232 237 6 Barapukuria 230 227 238 230 231 232 240 240 245 246 232 7 Bogra 229 226 236 230 233 234 231 264 240 237 234 8 Khulna South 242 242 244 241 244 244 244 238 241 239 244 9 Rampura 221 220 221 236 230 233 231 233 228 228 233 10 Haripur 219 227 219 221 226 232 232 235 230 228 232 11 Hasnabad 223 224 223 225 230 236 236 236 233 232 236 12 Aminbazar 222 222 223 224 244 235 237 242 234 231 235 13 Tongi 231 222 227 226 242 235 234 232 233 230 235 14 Comilla (N) 229 227 230 232 237 241 242 236 236 235 241 15 Hathazari 222 222 227 222 230 233 232 230 230 230 233 16 Megnaghat 224 225 224 228 240 238 240 242 235 232 238 17 Fenchuganj 239 240 243 243 248 245 245 240 248 240 245 18 Siddhirganj 234 237 244 242 241 242 242 240 237 228 242 19 Maniknagar 231 236 243 240 243 240 242 239 236 230 240 20 Old Airport 221 221 220 224 229 233 236 241 240 231 233 21 Barisal 238 241 246 239 244 241 240 248 243 244 241 22 AKSML 220 220 224 224 227 233 233 228 227 227 233 23 BSRM 221 223 226 226 230 236 236 230 235 232 236 24 Bibiyana 236 240 244 243 245 247 236 247 238 245 (Source: The Study Team)
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Table 4-5 MAX Voltage of 132kV Grid Sub-Station (2017-2018)
No. Name Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb. Mar. Apr. May. Jan. 1 Siddhirganj 138 139 141 140 138 140 141 140 138 139 140 2 Munsiganj 138 139 141 140 138 140 141 140 138 140 140 3 Megnaghat 137 134 136 138 137 139 140 145 134 138 139 4 Shyampur 132 135 134 134 135 138 137 139 137 136 138 5 Bhulta 127 130 130 129 132 139 143 145 140 142 139 6 Madanganj 135 134 137 138 137 140 140 140 142 139 140 7 Shitalakhya 137 139 136 138 141 140 141 146 144 140 140 8 Rahim Steal 136 137 138 138 139 140 140 138 138 138 140 9 Matuail 136 136 138 138 137 139 139 140 138 137 139 10 Ghorasal 140 140 140 140 140 144 142 145 144 145 144 11 Narsinghdi 139 137 138 139 137 136 142 138 141 136 136 12 Haripur (SBU) 136 137 139 138 138 141 140 138 137 138 141 13 Ullon 134 135 136 137 136 137 138 139 139 140 137 14 Hasnabad 135 136 136 136 138 138 138 143 140 138 138 15 Magbazar 134 135 137 135 135 138 138 134 149 141 138 16 Maniknagar 136 138 143 139 139 135 142 140 144 139 135 17 Bangabhaban 132 136 135 135 139 138 142 144 140 140 138 18 Narinda 134 135 136 136 135 136 136 140 139 141 136 19 Dhanmondi 135 135 138 138 136 137 139 140 144 140 137 20 Lalbag 132 136 134 135 139 138 142 145 140 140 138 21 Madartek 134 135 136 136 135 137 136 140 139 141 137 22 Mirpur 131 132 132 135 139 139 138 140 141 138 139 23 Kalyanpur 135 135 136 137 140 140 138 142 141 137 140 24 Gulshan 134 135 136 136 135 137 136 139 139 140 137 25 Uttara 133 132 134 140 137 138 136 143 138 136 138 26 Kamrangirchar 134 136 135 136 139 139 142 145 141 138 139 27 Savar 133 134 134 135 137 137 135 141 139 136 137 28 Bhasantec 132 134 136 138 138 136 136 144 136 136 136 29 Agargaon 132 135 137 139 138 136 136 144 137 135 136 30 Satmosjid 136 134 136 138 138 136 136 144 136 134 136 31 Tongi 138 138 141 141 140 140 140 142 146 142 140 32 Kabirpur 139 138 140 138 138 141 140 140 139 142 141 33 Basundhara 138 135 137 137 137 137 137 138 135 137 137 34 Manikganj 141 141 146 145 146 145 144 145 145 144 145 35 Joydevpur 140 143 147 142 143 143 144 145 145 144 143 36 New Tongi 138 139 141 141 141 141 140 144 140 142 141 37 Kodda 138 140 140 142 140 144 144 140 38 Tangail 137 140 143 140 140 140 140 140 145 145 140 39 Mymensing 136 138 144 137 140 140 138 144 140 142 140 40 Kishorganj 137 136 140 138 137 138 138 143 142 140 138 41 Netrokona 134 140 142 137 140 140 140 142 144 140 140 42 Jamalpur 134 137 141 135 135 140 138 147 138 142 140 43 Sherpur 136 138 143 138 141 141 145 145 140 143 141 44 Srimongal 140 140 141 142 142 144 145 143 145 142 144 45 Shahjibazar 138 139 141 142 142 143 143 144 140 141 143 46 Fenchuganj 137 137 139 140 140 143 142 141 141 138 143 47 Khulawara 136 137 138 139 140 144 141 140 140 136 144 48 Sylhet 136 135 137 139 138 142 141 139 140 142 142 49 Chattak 135 135 138 137 138 142 142 139 139 139 142 50 Comilla(South) 133 133 135 136 133 134 135 138 138 139 134 51 Comilla (North) 136 137 138 138 140 145 144 145 142 140 145 52 Chandpur 131 138 140 138 138 140 140 139 142 138 140 53 Feni 137 124 127 135 137 131 130 128 135 130 131 54 Chowmuhani 128 129 136 133 133 137 136 136 136 137 137 55 Ashuganj 140 140 144 143 145 145 145 146 142 143 145
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56 Daudkandi 137 135 138 140 138 141 141 141 141 142 141 57 Brahminbaria 138 139 141 141 142 143 144 146 142 142 143 58 Madanhat 134 135 138 136 138 140 140 138 136 141 140 59 Hathazari 132 132 137 132 136 138 140 135 135 134 138 60 Khulshi 133 129 137 130 138 136 137 133 134 137 136 61 Halishahar 131 131 134 132 136 140 140 135 136 140 140 62 Baraulia 130 130 134 132 135 137 138 134 133 133 137 63 Sikalbaha 131 132 134 133 136 139 139 136 134 138 139 64 Dohazari 130 133 135 132 136 139 140 134 136 135 139 65 Cox'sbazar 128 131 132 129 133 136 136 132 132 135 136 66 Chandraghona 131 131 135 135 136 138 139 134 135 139 138 67 Kaptai 134 132 135 134 136 140 140 135 136 135 140 68 A. Khaer Stl. 130 130 134 130 134 136 136 132 136 133 136 69 Bakulia 129 131 132 131 134 137 138 132 134 137 137 70 Julda 130 132 134 134 135 138 139 133 133 135 138 71 TK Chemical 133 134 136 135 138 141 142 137 138 137 141 72 Modern Steel 130 131 134 133 136 137 137 132 134 133 137 73 Shahmirpur 129 131 134 132 135 138 137 132 135 134 138 74 Goalpara 139 138 138 138 139 140 142 140 140 141 140 75 Khulna Central 139 139 139 139 139 139 141 140 140 139 139 76 Noapara 138 137 138 137 137 137 140 137 140 139 137 77 Jessore 133 136 136 130 132 133 135 134 138 136 133 78 Jhenida 135 134 135 136 136 135 140 139 140 139 135 79 Bottail 135 135 138 137 140 140 144 141 142 144 140 80 G.K.Project 137 137 140 138 144 142 146 145 144 144 142 81 Faridpur 136 134 138 133 135 135 140 139 140 141 135 82 Madaripur 136 135 140 135 136 136 140 142 142 142 136 83 Gopalganj 141 138 143 138 139 139 142 145 146 146 139 84 Bagerhat 138 141 140 138 140 140 140 140 141 141 140 85 Mongla 137 136 136 135 137 136 138 135 140 138 136 86 Satkhira 138 137 138 137 138 139 141 139 141 141 139 87 Gallamari 139 139 139 139 139 140 140 140 141 141 140 88 Magura 134 130 138 135 137 138 142 140 142 140 138 89 Chuadanga 130 129 136 134 136 136 137 139 138 139 136 90 Barisal 140 142 140 138 139 141 140 142 142 142 141 91 Patuakhali 140 142 140 138 139 141 140 142 142 142 141 92 Bhandaria 137 135 140 136 137 140 137 140 140 140 140 93 Ishurdi 136 135 139 136 139 140 145 160 144 145 140 94 Ruppur Paromanobik 134 138 134 134 141 142 138 95 Natore 137 137 140 137 140 140 144 160 144 141 140 96 Bogra 137 136 143 138 139 140 142 160 142 143 140 97 Noagaon 135 132 141 134 134 136 142 150 140 146 136 98 Rajshahi 138 137 138 136 137 136 140 146 142 138 136 99 C.Nawabganj 135 138 138 135 137 134 138 144 140 138 134 100 Amnura 140 140 140 140 139 142 140 140 142 140 142 101 Pabna 138 131 135 132 135 135 135 152 140 140 135 102 Shahjadpur 140 139 142 139 140 142 145 150 145 145 142 103 Serajganj 136 134 140 136 137 138 143 150 142 142 138 104 Niyamatpur 135 135 143 134 135 137 143 150 143 142 137 105 Joypurhat 136 136 142 135 137 137 144 150 144 144 137 106 Rangpur 129 127 133 129 136 130 134 141 136 138 130 107 Lalmonirhat 127 128 137 130 130 130 135 143 141 143 130 108 Saidpur 129 125 135 130 130 130 134 138 138 140 130 109 Purbasadipur 132 132 135 130 132 132 134 140 143 145 132 110 Thakurgaon 130 121 132 124 130 126 130 138 140 145 126 111 Palashbari 127 127 135 130 131 131 136 142 140 140 131 112 Barapukuria 130 127 135 130 131 132 140 140 145 146 132 113 Panchagar 125 119 130 124 130 125 129 137 138 147 125 (Source: The Study Team)
4-9 b. Minimum Voltages Table 4-6, Table 4-7, and Table 4-8 show the records of minimum voltages at each substation from July 2017 through June 2018. In these tables, the cells colored in light blue contain a minimum voltage that deviates from the reference voltage -5%, and the cells colored in dark blue contain a minimum voltage that deviates from the reference voltage -10%.
There are more substations whose minimum voltages deviate from the reference voltage -10% than those whose maximum voltages deviate from the reference voltage +10%. There are not a sufficient number of generators near the regions where electricity demand is high such as Dhaka and Chittagong. In such regions, voltages tend to decrease due to a shortage of reactive power.
Table 4-6 min Voltage of 400kV Grid Sub-Station (2017-2018)
No. Name Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb. Mar. Apr. May. Jan. 1 Bibiyana 371 400 365 393 379 368 374 380 376 2 Bheramara 362 357 373 401 396 393 379 388 384 3 Kaliakoir 347 269 365 383 363 344 340 353 353 (Source: The Study Team)
Table 4-7 min Voltage of 230kV Grid Sub-Station (2017-2018)
No. Name Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb. Mar. Apr. May. Jan. 1 Ghorasal 220 220 220 220 220 225 226 220 220 222 225 2 Ishurdi 226 223 225 226 215 227 218 213 211 220 227 3 Ashuganj 229 225 227 228 228 234 228 225 214 225 234 4 Serajganj 210 210 206 212 208 214 212 202 208 210 214 5 Baghabari 216 212 214 200 213 219 217 208 202 200 219 6 Barapukuria 214 210 208 213 215 216 212 220 214 220 216 7 Bogra 210 204 200 209 206 212 208 200 203 207 212 8 Khulna South 138 229 228 222 211 218 211 214 215 206 218 9 Rampura 210 206 209 208 214 214 217 212 205 216 214 10 Haripur 211 205 206 208 213 213 218 215 215 215 213 11 Hasnabad 212 206 201 206 215 215 220 214 215 212 215 12 Aminbazar 211 203 205 206 215 215 219 215 210 213 215 13 Tongi 202 200 200 203 212 220 212 203 204 205 220 14 Comilla (N) 220 216 216 218 220 228 225 215 215 220 228 15 Hathazari 208 205 200 205 206 205 210 203 205 202 205 16 Megnaghat 217 208 210 210 217 221 218 218 220 219 221 17 Fenchuganj 229 227 227 224 210 235 224 218 211 225 235 18 Siddhirganj 213 211 208 217 212 209 213 212 208 207 209 19 Maniknagar 210 208 206 215 212 210 211 209 208 205 210 20 Old Airport 210 202 202 204 211 216 218 213 212 210 216 21 Barisal 218 200 219 221 219 226 224 224 213 218 226 22 AKSML 203 202 197 201 205 206 205 201 203 202 206 23 BSRM 206 204 203 207 208 211 210 207 206 206 211 24 Bibiyana #N/A 215 227 231 231 233 227 217 218 223 233 (Source: The Study Team)
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Table 4-8 min Voltage of 132kV Grid Sub-Station (2017-2018)
No. Name Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb. Mar. Apr. May. Jan. 1 Siddhirganj 128 127 125 127 128 131 124 124 123 125 131 2 Munsiganj 127 126 125 127 128 130 124 125 124 126 130 3 Megnaghat 126 126 126 127 128 130 124 125 122 126 130 4 Shyampur 119 122 114 117 120 125 120 120 119 120 125 5 Bhulta 118 117 115 114 119 120 120 126 124 118 120 6 Madanganj 124 124 125 122 126 130 123 125 125 124 130 7 Shitalakhya 123 124 123 122 125 126 124 126 126 125 126 8 Rahim Steal 127 126 124 126 129 132 126 125 123 126 132 9 Matuail 125 124 124 126 119 118 118 123 122 124 118 10 Ghorasal 130 128 130 130 135 135 133 125 130 130 135 11 Narsinghdi 123 122 119 125 127 134 120 121 119 122 134 12 Haripur (SBU) 128 126 124 129 129 130 127 125 124 125 130 13 Ullon 124 120 121 122 123 125 122 120 120 126 125 14 Hasnabad 125 124 125 123 125 126 125 124 127 126 126 15 Magbazar 122 120 121 120 115 125 122 110 120 125 125 16 Maniknagar 123 120 122 126 118 119 120 124 125 123 119 17 Bangabhaban 123 120 122 126 118 119 120 124 125 123 119 18 Narinda 123 121 122 127 118 116 120 126 125 128 116 19 Dhanmondi 123 120 122 122 118 120 122 120 120 126 120 20 Lalbag 120 118 118 118 122 121 120 124 124 119 121 21 Madartek 123 120 121 121 124 126 122 120 121 126 126 22 Mirpur 121 116 119 116 124 126 120 125 122 123 126 23 Kalyanpur 123 124 123 123 129 128 120 125 123 125 128 24 Gulshan 124 120 121 121 123 126 121 120 120 119 126 25 Uttara 119 114 120 118 125 126 122 118 120 113 126 26 Kamrangirchar 122 119 120 117 124 123 122 124 121 123 123 27 Savar 123 118 120 119 125 126 122 121 120 119 126 28 Bhasantec 122 120 120 123 124 126 121 120 121 118 126 29 Agargaon 123 121 123 123 126 127 124 121 119 120 127 30 Satmosjid 120 120 121 124 125 125 123 121 120 119 125 31 Tongi 124 121 122 124 126 128 125 120 124 122 128 32 Kabirpur 120 118 120 122 125 127 120 118 120 120 127 33 Basundhara 122 119 120 122 120 127 122 118 117 120 127 34 Manikganj 96 120 123 126 130 134 124 123 128 126 134 35 Joydevpur 113 124 124 127 132 129 129 127 124 125 129 36 New Tongi 123 120 122 124 128 130 123 118 123 121 130 37 Kodda #N/A #N/A #N/A 127 131 130 130 124 121 126 130 38 Tangail 116 115 115 119 121 125 120 112 118 120 125 39 Mymensing 111 112 117 120 124 119 107 109 111 107 119 40 Kishorganj 115 120 123 125 127 126 115 114 115 113 126 41 Netrokona 104 110 117 121 120 115 113 108 110 105 115 42 Jamalpur 111 108 113 117 114 115 107 108 107 108 115 43 Sherpur 110 109 111 116 115 115 108 105 110 107 115 44 Srimongal 132 133 134 127 137 137 136 125 129 127 137 45 Shahjibazar 130 130 124 131 136 137 134 125 127 127 137 46 Fenchuganj 131 131 131 133 135 133 133 128 126 126 133 47 Khulawara 130 131 130 133 132 132 130 127 125 122 132 48 Sylhet 128 127 126 131 133 131 129 122 123 120 131 49 Chattak 124 123 120 129 132 125 127 121 122 124 125 50 Comilla(South) 117 110 118 119 122 123 122 118 119 117 123 51 Comilla (North) 129 121 128 124 133 126 133 128 120 125 126 52 Chandpur 120 112 120 120 125 122 128 115 116 119 122 53 Feni 115 110 115 118 120 120 118 114 113 113 120 54 Chowmuhani 115 110 109 118 122 111 117 114 111 116 111 55 Ashuganj 131 131 135 122 137 138 135 121 127 125 138
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56 Daudkandi 125 123 124 127 129 121 129 108 126 125 121 57 Brahminbaria 128 129 132 128 134 136 125 120 127 123 136 58 Madanhat 126 125 121 126 127 126 126 120 126 123 126 59 Hathazari 124 121 120 124 125 125 124 119 107 120 125 60 Khulshi 120 119 116 119 122 119 121 109 120 118 119 61 Halishahar 121 119 118 121 122 122 118 110 122 121 122 62 Baraulia 120 119 118 110 121 120 123 113 115 107 120 63 Sikalbaha 121 119 118 120 120 121 123 117 123 122 121 64 Dohazari 122 120 119 119 122 122 122 120 115 118 122 65 Cox'sbazar 115 109 111 115 119 116 113 112 110 111 116 66 Chandraghona 123 122 120 124 125 122 125 114 107 115 122 67 Kaptai 125 125 125 124 126 124 126 125 125 122 124 68 A. Khaer Stl. 119 121 120 120 122 124 124 116 121 120 124 69 Bakulia 119 119 116 119 121 120 122 118 121 120 120 70 Julda 121 117 118 120 121 121 123 110 122 120 121 71 TK Chemical 124 123 121 124 123 125 127 125 123 124 125 72 Modern Steel 120 119 117 119 121 122 108 115 120 119 122 73 Shahmirpur 121 117 118 121 121 120 123 115 122 121 120 74 Goalpara 127 131 130 128 120 122 119 124 120 118 122 75 Khulna Central 127 124 132 128 121 121 120 125 125 120 121 76 Noapara 125 127 127 125 120 118 120 121 120 118 118 77 Jessore 118 119 120 120 115 111 110 114 117 117 111 78 Jhenida 116 117 115 117 113 106 107 113 110 109 106 79 Bottail 120 117 124 125 125 125 110 120 112 120 125 80 G.K.Project 131 125 123 128 129 130 127 116 122 130 130 81 Faridpur 123 118 122 120 123 125 123 122 121 120 125 82 Madaripur 122 121 123 123 124 123 122 120 120 122 123 83 Gopalganj 121 116 118 118 119 120 119 118 118 118 120 84 Bagerhat 129 130 130 121 120 121 120 121 122 120 121 85 Mongla 124 127 127 118 120 118 117 121 120 113 118 86 Satkhira 127 129 130 128 121 123 121 125 122 121 123 87 Gallamari 129 119 132 127 123 122 121 121 122 122 122 88 Magura 115 115 115 115 119 110 106 112 108 107 110 89 Chuadanga 109 109 109 115 115 101 104 106 104 105 101 90 Barisal 125 128 130 130 126 130 123 127 125 126 130 91 Patuakhali 125 128 130 130 126 130 123 127 125 126 130 92 Bhandaria 124 122 125 120 125 120 125 124 120 120 120 93 Ishurdi 129 127 128 127 124 129 124 124 122 130 129 94 Ruppur Paromanobik #N/A #N/A #N/A #N/A 130 130 129 129 121 131 130 95 Natore 126 125 122 125 123 127 119 120 121 126 127 96 Bogra 122 118 118 124 123 124 113 111 106 119 124 97 Noagaon 118 115 114 121 119 120 111 110 113 115 120 98 Rajshahi 123 124 123 124 123 123 121 119 121 125 123 99 C.Nawabganj 121 116 122 120 120 120 119 116 118 120 120 100 Amnura 120 120 120 122 120 120 120 119 115 118 120 101 Pabna 124 122 106 124 122 120 120 120 118 124 120 102 Shahjadpur 130 124 117 131 129 131 125 130 115 131 131 103 Serajganj 120 123 119 125 125 123 122 114 115 123 123 104 Niyamatpur 112 111 113 118 117 113 105 107 108 111 113 105 Joypurhat 116 113 114 120 118 117 111 111 110 111 117 106 Rangpur 106 109 107 109 112 109 104 105 100 108 109 107 Lalmonirhat 100 100 100 104 103 102 97 104 105 100 102 108 Saidpur 104 105 104 108 108 106 101 103 108 104 106 109 Purbasadipur 107 108 103 110 110 112 105 104 118 112 112 110 Thakurgaon 98 95 95 100 100 104 95 103 103 105 104 111 Palashbari 110 103 110 115 114 112 110 108 105 110 112 112 Barapukuria 114 110 108 113 115 116 112 108 122 120 116 113 Panchagar 93 90 94 95 96 99 92 98 100 98 99 (Source: The Study Team)
4-12 c. Voltage Supervision and Control With respect to voltage supervision, the grid code stipulates that "strategic substations" must be continuously supervised. In each table, the substations whose names are shown in red are "strategic substations."
(5) Data Maintenance With respect to the maintenance of facility data stored in SCADA upon installation of a new facility, because the construction of a new substation or new transmission line is ordered on a full-turnkey basis, the maintenance of SCADA data is covered by the construction work contract. The contractor for construction work commissions the data maintenance work to an SCADA vendor so that the electric power system including the new facility will be reflected in SCADA. In many cases, the maintenance of SCADA data is conducted about one or two months after the completion of a new facility, but there are cases where this procedure is taken later than that.
Training (1) Training Policy Figure 4-5 shows the types of training available at PGCB. There are two types of off-the-job training: one is training received in foreign countries or at external institutions, and the other is training received in Bangladesh. The type of training received in Bangladesh is classified further into two types: one conducted in a training center for a group of operators and the other conducted in each region. All PGCB employees are required to receive this training for a total of 70 hours each year.
The training programs offered by facility manufacturers and external institutions are included in the training for 70 hours a year. The contents of these 70-hour training programs range from general administration to special training specific to the employee's post and responsibility.
(Source: The Study Team) Figure 4-5 Types of training
(2) Training Resources PGCB is conducting programs to provide in-house training to its operators. As the first step, PGCB is launching a program to develop a team of 5 to 7 operators as the trainers of a maintenance unit of steel towers and transmission lines called "Training of Trainers." Once this
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program is completed successfully, PGCB will conduct similar programs for other types of workers and develop about 30 trainers in the next three years.
(3) Training for operators PGCB is currently focusing on on-the-job training for operators rather than off-the-job training for them. The operators at BCC are sent to NLDC once or twice a month to work face-to-face with NLDC operators, experience NLDC operations, and maintain their skills at a high level. On the other hand, there are some ALDCs and substations where only one operator is working due to the shortage of operators. In such a case, a supervisor in these workplaces is providing on- the-job training, or NLDC is providing on-the-job training over the phone.
(4) Other Programs In the past, training conducted outside Bangladesh was intended only for management-level employees. However, as a new initiative directed at staff-level employees, PGCB has a plan to send about 30 engineers to an Indian electric power company for a month.
Unable to communicate well in English, PGCB engineers will have to break the language barrier before receiving training programs conducted in foreign countries. But because its engineers can communicate in Bengali in the western part of India, PGCB decided to plan this exchange program. Once this program is completed successfully, PGCB will continue this relationship with the Indian Electric Power Company.
4.2 Facilities SCADA/EMS Since the start of its operation in 2010, the existing SCADA/EMS has been in service for about eight years. Although the service life of the hardware is already over, the policy on next- generation SCADA/EMS has yet to be determined. Furthermore, considering the facility expansion plans in the future, PGCB also has many problems with its supervisory control system. Not having developed its specific policy on the supervisory control system, PGCB is unable to work out a facility replacement plan. Given this background, PGCB already planned and authorized the replacement of SCADA/EMS hardware this year or next year. It is expected that the service life of the existing SCADA/EMS will be extended by about 5 to 8 years because of this hardware replacement.
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(1) Hardware Configuration The equipment connected to RTU LAN is the RTUs of substations. The equipment connected to SCADA LAN includes each function server of SCADA, workstations for operational use, workstations for maintenance use, and a supervisory control terminal.
(2) Applications The function for adjusting electricity supply and demand is currently disabled due to a connection problem with other pieces of equipment. However, this function will be enabled through the upcoming "Bangladesh Power System Reliability and Efficiency Improvement Project of the World Bank."
Communication Network Figure 4-6 shows the configuration of the optical fiber network PGCB owns. PGCB sets up optical ground wires (OPGW), a type of cable that mounts optical fiber cable inside the overhead ground wire designed to protect high-voltage transmission lines from direct lightning strokes. PGCB has its proprietary power line carrier (PLC) communication system in place. However, because the speed of its existing PLC communication equipment is not at a satisfactory level, PGCB is trying to improve its communication system by installing high speed optical fibers using multiplexers.
As a result, the total length of the OPGW became 4,300km as of June 2012, and over 5,000km today (according to our hearing survey), covering most of the land of Bangladesh. Not just for PGCB itself, the optical fiber network has expanded rapidly enough to lease it to local telecommunications carriers and grow the country's communication infrastructure.
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(Source: PGCB Web site https://www.pgcb.org.bd/PGCB/) Figure 4-6 PGCB Optical Fiber Network
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5 Issues of Power Control Operation and Control Facilities Based on Future Facility Expansion 5.1 Power Control Operation Supervisory Control System If the number of substations increases in the future as forecasted in "3 Current Status and Future Outlook of Electricity Supply," the system of PGCB described in "4.1.1 Supervisory Control System" is expected to lose control. The following are the reasons.
(1) Division of Roles In normal times, NLDC orders each substation to conduct specific operations over the phone. But only when the balance between supply and demand becomes strained, NLDC will control load interruption at the substation by remote operation. Ordering all substations to conduct operations over the phone will increase the workload of NLDC if the number of substations increases in future.
(2) Workload It is expected that the workload of NLDC will build up with the increasing number of new facilities. While the details will be described in "5.1.2 Operation," workload related to power system control will increase in proportion to the number of new facilities. Furthermore, it is also expected that the existing plans for new generators will increase the complexity of electricity supply and demand control. This situation would not only increase the workload of staff-level employees but also increase the time supervisors must spend making decisions, possibly affecting PGCB's overall performance.
Operation (1) Supervisory Operation At present, alarm supervision for each equipment at substation is conducted by the substation. Equipment failures that affect the operation of the power system need to be reported to NLDC. It is considered that the number of facility problem reports from each substation will increase with the growing number of new facilities. Because only one operator is involved in transmission system control at NLDC, there is concern that necessary actions may not be taken when multiple problems occur at the same time.
(2) Switching Operation Scheduled outages are concentrated in the winter in Bangladesh because of high electricity demand and frequent cyclones in other seasons. According to our surveys, it was learned that each facility needs to be shut down for inspection and maintenance once a year. This means that the number of scheduled outages will increase with the growing number of new facilities.
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In this case, there may be a problem in which some facilities cannot be shut down due to limitations of power system operation. There is concern that NLDC operators will become busy with multiple operations, which may lead to erroneous operations and delayed operations. They may not be able to spend sufficient time for inspection, paying less attention to operation safety.
(3) Data Recording Based on the number of numerical records prepared at each substation that was assumed in "4.1.2(3) Data Recording" and "3.4 Data for Verification," the workload needed to prepare records and reports in the future is estimated as follows. However, the records of generators are excluded from these log points because they are reported using the PGCB Intranet.
24000
20000
16000
12000
8000
4000
0 2018 2023 2028 2033 2038
Total Substation Transmission line
(Source: The Study Team)
Figure 5-1 Rough estimation of the log point of substations and transmission lines
The work needed to prepare these records and reports are burdensome even today. If this work must be continued into the future, the workload will double in 2022 and triple in 2033 compared to today's levels. Unless the number of operators is increased or how to conduct operations is changed, the total workload is expected to go beyond what ALDC and NLDC can possibly deal with.
(4) Voltage Regulation Being aware that voltages at each substation deviate from the maximum and minimum indicators, PGCB is faced with the problem of not knowing how to regulate these voltages within the range.
It seems that this problem can be solved by introducing an application that simulates voltages in its power systems and offers appropriate solutions. At a glance, however, there are many
5-2 substations where voltages deviate from the maximum and minimum indicators. It is a concern that the workload of voltage regulating operation will increase over time.
(5) Data Maintenance It seems that the timing of SCADA data maintenance lags because PGCB is not outsourcing SCADA data maintenance to an SCADA vendor. Furthermore, there is concern that as the number of new facilities will increase at a rapid pace, PGCB will lose track of what equipment will be added to SCADA and when.
Training At present, internal and external training programs are clearly classified in accordance with the "Training Policy." In addition, all employees are required to receive introductory training and develop an annual training plan, with a person in charge of training clearly indicated for each department. PGCB is well organized in its training system. Further, PGCB employees appear to be proactively receiving external and overseas training programs.
However, all of these are desktop training, and all skill coaching training is conducted as on-the- job training. Additionally, there is the problem that staff-level employees have limited opportunities to receive external training programs due to the language barrier.
Currently, trainer development programs are under way, albeit in a limited number of areas. It is necessary to expand the scope of such programs to other areas. It is also necessary to create an environment in which skill coaching training programs will be conducted as off-the-job training.
5.2 Facilities SCADA/EMS (1) Hardware Configuration First, concerning the internal configuration of SCADA, signals to be processed in real time are flowing through SCADA LAN, including switch ON/OFF data collected from on-site facilities, signals that transmit measurement data to operators, and signals that transmit control signals to on-site facilities.
In addition, other types of signals are also flowing through SCADA LAN, such as signals that do not require real-time processing as much as the above-mentioned signals, which include the preparation, storage, and invocation of operating procedures, the storage of records in archives, and the processing of power system simulation. In the existing architecture, all signals are transmitted through SCADA LAN. In the future, the number of signals flowing through the inside of SCADA will increase with the growing number of substations, which may increase the level of data traffic. It is therefore necessary to create a mechanism to separately process signals that must be processed in real time and other signals.
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(2) Applications As described earlier, the functions required for electricity supply and demand control will be developed through the "Bangladesh Power System Reliability and Efficiency Improvement Project of the World Bank." One of the kinds of issues that PGCB must solve is that the company introduced its SCADA/EMS with full functions built in despite the inability to connect it to some pieces of the existing equipment. In introducing SCADA/EMS, PGCB should design the SCADA/EMS on its own and introduce the best system.
In the meanwhile, PGCB is using almost all the functions required for power system control, but they are all conventional functions. These functions are not enough to solve the issues described in "5.1.2 Operation."
Communication network The current communication network equipment is enough to lease it to local telecommunications carriers, and there is no problem in particular. It is necessary to prepare for data traffic between the field device and SCADA with the growing number of field devices in the future.
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6 Improvements in Project Schemes 6.1 Operation Supervisory Control System (1) Delegation of Authority As a first step, it would be best to delegate the responsibility and authority for power system control NLDC holds to somewhere else in order to solve the issues described in "5.1.1(1) Division of Roles."
It seems that NLDC has been responding to more urgent problems first in both power system control and supply and demand control. If the authority of NLDC for power system control is delegated to somewhere else as shown in Figure 6-1, NLDC will be able to focus more on supply and demand control including less urgent problems. This setting would provide the benefit of realizing high-value-added operations.
The organization that can operate this type of function today is ALDCs. The details will be described in the next paragraph.
(Source: The Study Team)
Figure 6-1 Advantage of empowerment
(2) Organizational Configuration In order to delegate NLDC's authority for power system supervision control, new Load Dispatch Centres need to be set up at several locations so that all areas of Bangladesh will be covered. After ALDCs are set up to cover all Bangladeshi areas, the authority and responsibility for power system supervision control will be given to ALDCs. But because the electric power system is connected to all regions of the country, any operation conducted in one region in normal times or at the event of an outage will affect other regions. For this reason, these Load Dispatch Centres must be interconnected. Especially bulk power transmission lines, which are designed to transmit generated electric power throughout Bangladesh, require wide-area tidal current supervision capabilities. It is therefore difficult for supervisory control centers across the country to conduct the supervisory control of these bulk power transmission lines.
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Given this background, this study proposes the establishment of a Load Dispatch Centre that plays the roles of conducting the supervisory control of bulk power transmission lines and organizing the operations of all ALDCs. Figure 6-2 shows the best organizational configuration of the Load Dispatch Centre this study recommends.
(Source: The Study Team) Figure 6-2 Suitable monitoring and control organization
A new organization called the Bulk Load Dispatch Centre (BLDC) will be established. The following are the roles that BLDC should play.
Supervision and control of the bulk power system network Information sharing with NLDC that controls electricity supply and demand in normal times and emergency situations Cooperation with ALDCs for organized operations in power system supervision control Providing support to ALDCs in human resources development
Based on this proposal, NLDC can concentrate on the most important supply and demand control operations, allowing itself to strive for high-quality operations. When the balance between supply and demand is strained or in the event of an outage, NLDC needs to interact only with BLDC, which minimizes the workload of NLDC.
As one idea about the division of roles between BLDC and ALDCs, it is recommended that BLDC conducts the supervisory control of 400/230kV and 400/132kV substations and 400kV and 230kV transmission lines, and that ALDCs conduct the supervisory control of 230/132kV and 132/33kV substations and 132kV transmission lines.
In this setting, BLDC will conduct the supervisory control of 230kV-or-higher bulk power systems
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throughout Bangladesh, and each ALDC will conduct the supervisory control of 132kV area power systems in its territory. However, there is the need to set rules for the authority for the 132kV side of 400/132kV substations and the 230kV side of 230/132kV substations, including the need of close interaction between concerned BLDC and ALDC.
It is desirable that BLDC will eventually delegate its authority for 132kV-or-lower power systems to ALDCs. When considering the delegation of authority, it is necessary to make sure the facilities to which the authority will be delegated have qualified human resources. However, it is realistically impossible to find such human resources at ALDCs at the starting point. It is therefore desirable that BLDC will deploy human resources with experience of conducting power system supervision control at NLDC, and that BLDC will support ALDC in developing qualified operators and gradually developing an ideal form of organization.
In the meantime, new BLDC can be set up at any location. If there is enough space, establishing BLDC right next to NLDC makes a lot of sense in terms of effective interaction between the two. Alternatively, establishing BLDC right next to the Backup Control Center (BCC) of NLDC would allow BLDC to back up NLDC when it becomes unable to conduct supervisory control.
Operation In this section, the opportunities for automating ongoing operations using SCADA will be studied in order to solve the problem of operator shortage.
(1) Supervisory Operation One supervisory control center is supervising several dozen of substations at the same time. For this reason, there is the need for computer screens designed to classify incoming information into those that require alarming and those that do not and to help grasp necessary information quickly.
(2) Switching Operation PGCB can prepare and store procedures for switching operations in advance. PGCB also can refer to the procedures used in the past in preparing new procedures. These facts make us believe that PGCB's switching operations are streamlined to a certain degree. Further efficiency improvements might be possible by automating the preparation of procedures for switching operations. It seems possible to automatically prepare procedures for simple processes such as for stopping a single facility, which can be ordered using a typical procedure.
At present, NLDC or each ALDC is instructing substations over the phone to follow "Purpose of Switching" as shown in Figure 4-4, and the substations are implementing the procedures line by line. In this case, the use of remote operation directly from SCADA would be more efficient. If specifications are designed to automatically implement procedures for each piece of equipment line by line simply by executing the command of "Purpose of Switching," virtually nothing will change from the previous procedures, resulting in smooth transition.
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(3) Data Recording PGCB should pursue the automation of data recording as well. The need of reporting data over the phone every hour is burdensome for substations, NLDC, and ALDCs. PGCB is currently using a predetermined format for data reporting. If there is a function that can automatically output data collected by SCADA into that format, the efficiency of data reporting is expected to improve significantly.
But there is the need to set rules before changing this procedure for data reporting. The reasons why PGCB is not using data collected by SCADA today include missing pieces of data and measurement errors.
With respect to missing pieces of data, it is necessary to set up rules for some functions of SCADA. For example, when finding an apparently strange data point, SCADA must remove it and adopt a value estimated from the previous and next data points.
As to measurement errors, at the start of operation of a piece of equipment, the values displayed at the substation and NLDC must be carefully checked to see whether they are identical. If there are any discrepancies in measurements, a calibration test must be conducted. In addition, the equipment in operation must be checked regularly to see whether there are any discrepancies in measurements between the substation and NLDC.
(4) Voltage Regulation With respect to voltage regulation, there is the need for a function that can judge whether the transformer tap must be stepped up or down, or whether the switch of the phase modifying equipment must be turned ON or OFF, when voltages deviate from the target level and must be brought back into an adequate range.
At present, the shape of daily electrical load curves of Bangladesh is moderate. It is unknown how this shape will change with increasing electricity demand in the future. Furthermore, when the use of renewable energy increases in the future, changes in the weather may affect electricity demand and voltages.
It is likely that voltages need to be regulated frequently in the future, and the introduction of a function that can automatically adjust voltages to SCADA is recommended. As described in "5.1.2(2) Switching Operation," the number of scheduled outages is expected to increase in the future and the number of operations will increase accordingly. This is why the automated regulation of voltages is recommended.
(5) Data Maintenance Upon new facility installation, it is recommended that PGCB outsource SCADA data maintenance directly to an SCADA vendor. For example, if PGCB itself controls the schedule of SCADA data
6-4 maintenance by conducting the data maintenance of multiple facilities every month, it will prevent data maintenance from lagging behind the start of operation of a new facility.
(Source: The Study Team) Figure 6-3 Proposal of SCADA data maintenance ordering method
Training At present, PGCB is having its operators receive external training programs proactively, and this approach should be continued. However, most of these external training programs are one-time events, which are not suited for long-term practical training. Even if PGCB plans long-term operator training programs with the help of external programs, it would cost the company a lot, and all operators may not be able to receive such training programs. Moreover, the number of operators who can receive such training programs is limited because of the language barrier.
Given this background, the introduction of in-house training is necessary to improve the skills of all operators. In this case, practical skill training by internal trainers familiar with internal rules would enable coaching reflecting the company's actual conditions. This type of internal training would allow operators to learn practical skills in their workplaces. This approach also makes it easy to benchmark the level of skills acquired, and the company can foster its operators on an ongoing basis, while checking the pace of their growth at the same time.
However, conducting in-house practical skill training for all operators would involve the assignment of internal trainers and the creation of a training environment, which requires a lot of time.
Given this background, this study offers a proposal in which human resources will be brought up while developing the training environment in incremental steps.
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6.2 Facilities SCADA (1) Hardware Configuration a. System configuration The main system configuration of the proposed SCADA remains unchanged from the existing SCADA, with FEPs and servers installed at Server Base. Thin client terminals are installed at supervisory control organizations to supervise/control electric power systems. These terminals are installed at places where display terminals need to be monitored. b. Service Bus Information has different levels of priorities. When many types of information are bundled into one bus, high-priority information may not be processed in real-time due to data traffic caused by low-priority information. This issue can be solved by using different buses depending on the priority of information. c. Gateway Gateways are installed between substation SAS and RTU and SCADA FEP. The details will be described in "6.2.2 Communication Network".
(2) Application Configuration a. Automated procedure preparations, operational functions When it comes to controlling on-site facilities directly from BLDC or ALDC, BLDC or ALDC needs to prepare not only the procedure for "Purpose of Switching" but also the procedure for each piece of equipment. If SCADA has a function that can read in the procedure for each of the related pieces of equipment when preparing "Purpose of Switching," the streamlining of procedure preparations may be possible. If the procedure for each of the related pieces of equipment can be automatically executed when "Purpose of Switching" is executed, the workload of the operator will be reduced. b. Data output function The timing and format of records and reports are predetermined. If SCADA has a function that can store and output records and reports in these predetermined format and time, a significant increase in efficiency may be expected. c. Voltage regulation function SCADA needs to have a function that informs the details of appropriate operations, or conducts such operations automatically, when the voltage is found to deviate from an adequate voltage range during bus bar voltage supervision at each station. If PGCB has a plan to introduce phase modifying equipment in the future, SCADA needs to have a function that monitors reactive
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power.
Communication Network The communication network in Bangladesh is well-organized, and there are few short-term challenges. However, the level of data traffic may increase with the increasing number of substations and growing amount of incoming information in the future. For this reason, the need to introduce more efficient communication methods may arise in the future.
6.3 Project Implementation Structure and Schedule Our proposal based on the results of this survey would require the construction of a new supervisory control system and the introduction of a new SCADA for system supervisory control. At present, PGCB does not have the ability to design the best SCADA specifications on its own. For this reason, PGCB must start with human resources development.
The electric power system operators PGCB has today are limited to those at NLDC. Although PGCB has many substation operators, none of them have experience with electric power system operation. The new supervisory control system would require system operators at BLDC and ALDC locations, meaning that PGCB will need to have more system operators than the center has today.
However, PGCB has neither training plans nor training programs for developing system operators. In order to develop the many system operators that will be required in the future, the implementation of system operator training programs is recommended as a first step. The system operators developed through such training programs will be able to operate electric power systems and understand necessary SCADA requirements. The system operators developed in such a way will become operators at each supervisory control center under a new supervisory control system, or they are expected to become engineers who design necessary requirements for a new SCADA.
6.4 Result of Pre-Feasibility Study It was confirmed that our proposal based on the results of this survey is feasible in all aspects of supervisory control system, SCADA, operation, and training. The introduction of new operational practices would require detailed rule setting, and there is the need for our technical assistance.
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7 Benefits from Improvements in the Project 7.1 Expected Benefits for the Partner Country Minimizing the Increase in Personnel Expenses If facility expansion continues without revising the existing personnel plan, a large number of operators must be added at substations. However, if operations can be streamlined by establishing supervisory control systems as described in "6.1.1 Supervisory Control System" by conducting supervisory control at BLDC and by introducing a new SCADA, the number of operators at substations could be reduced from the current plan.
If additional personnel are deployed at each supervisory control center to directly supervise/control substations, the number of substation personnel could be reduced from the current plan. While it seems possible to introduce unmanned operation, this simulation assumed the abolition of three-shift rotations at substations and halving the number of substation personnel to half from the current plan.
Figure 7-1 shows the result of our simulation on the number of personnel.
4500
4000 Operator (In current plan) Operator (In tentative plan from 2024) 3500 Operator (In tentative plan from 2021)
3000
2500
2000 Personnel
1500
1000
500
0 2018 2023 2028 2033 2038 Year
(Source: The Study Team) Figure 7-1 Comparison of personnel in each plan
Assuming that a new SCADA will be introduced in 2024 and supervision/control under a new system will start at the same time, the number of operators required will increase as shown by the orange solid line in Figure 7-1, about 75% of the number of the current plan as of 2041. However, given the long-term plan that many facilities will be expanded by 2023, the current personnel plans should be reviewed earlier. Because the scale of power grids in Bangladesh is not large today, it seems possible to deal with future facility expansion by building supervisory control systems as early as possible and by installing the terminals of the existing SCADA at new
7-1 supervisory control centers. In this case, the number of personnel required will change as shown by the orange dotted line in Figure 7-1, about 80% of the number of the current plan even as of 2023 then about 65% as of 2041. In order to start building supervisory control systems as early as possible, the installation of simulators to train operators should be started earlier than the introduction of a new SCADA. Once the supervisory control systems are put in place, the continuously expanding electric power system can be operated in an efficient manner by the introduction of a new SCADA and the expanded scope of training programs.
Reductions in Economic Losses by Shortening Power Outages It is obvious that even in Bangladesh, the occurrence of power outages interrupts its economic activities to a certain degree. The cost of such economic losses is estimated here. First, Figure 7-2 shows the status of power outages in Bangladesh.
3000
2500
2000
1500 [MWh] 1000
500
0 Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb. Mar. Apr. May Jun.
T E/O S/O
(Source: PGCB Web site https://www.pgcb.org.bd/PGCB/)
Figure 7-2 Summary of unserved energy (2017-2018)
According to an estimate by the Central Research Institute for Electric Power Industry1, economic losses from power outages are considered to be somewhere between 300 and 1,000 yen/kWh, however this is based on Japanese data. This survey was conducted based on a power outage loss of 883 yen/kWh, a value estimated using an analysis technique. Losses from power outages in Japan cannot be applied directly to similar losses in Bangladesh. For this reason, economic losses from power outages in Bangladesh were estimated based on Japan's GDP in 2011 and Bangladesh GDP in 2017 and 2018 (estimated): 0.43 dollars/kWh (2017) and 0.48 dollars/kWh (2018). Based on these economic losses per kWh and the actual unserved energy shown in Figure 7-2Figure 7-2, total economic losses from power outages in Bangladesh were estimated as shown in Figure 7-3.
1 Takeo Imanaka, Overview of Electricity Supply-Demand Curve, the Central Research Institute for Electric Power Industry, 2011
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5 14
12 4 10
3 8
2 6 4 1
Monthly $] Monthly Loss [million 2 Cumulative loss [million loss [million $] Cumulative
0 0 Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb. Mar. Apr. May. Jun.
T E/O S/O Cumulative
(Source: The Study Team) Figure 7-3 The economical loss caused by outage
According to this estimate, Bangladesh is losing 12 million dollars every year due to power outages. If the time needed to recover from power outages can be decreased by 10% by developing supervisory control systems, upgrading the existing SCADA, and providing training to operators, economic losses due to power outages can be reduced by more than 1 million dollars. This estimate was based on economic losses due to power outages in Japan, and it is not known if Bangladesh will experience similar levels of economic losses. However, it is expected that Bangladesh will see its economic losses caused by power outages increasing in the future since it is aiming to become an advanced country by 2041. In this sense, it is important to try to shorten power outages.
Reducing Loss in Leased Transmission Fees Figure 7-2 showed the amount of unserved energy due to power outages. This means that Bangladesh is missing the amount of leased transmission fees equivalent to the length of power outages. The reduction in power outages will decrease the loss in expected leased transmission fees.
7.2 Estimating CO2 Emission Reductions According to the World Bank data, carbon dioxide emissions in Bangladesh were approximately 73,000kt in 2014. In Bangladesh, the power sector accounts for about one-third of the total energy consumption, which means that the power sector is emitting approximately 24,000kt of carbon dioxide every year. Electricity transmission company PGCB can contribute to the reduction of carbon dioxide emissions by decreasing the transmission loss as shown in Figure 7-4.
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5%
4% 2.92% 2.70% 2.82% 2.77% 2.86% 3% 2.72% 2.67%
2%
1%
0% 2011 2012 2013 2014 2015 2016 2017
(Source: PGCB Annual Report 2016-2017) Figure 7-4 Transmission Loss of PGCB
One of the effective measures to reduce transmission loss is proper management of transmission voltage. As described in "4.1.2(4) Voltage Regulation" transmission voltage deviates from the standard voltage at many substations. Of these substations, a larger number of substations were seen operating at a transmission voltage lower than the standard voltage. Power transmission at a higher voltage helps reduce transmission loss. For this reason, transmission loss could be reduced by introducing the function proposed in "6.2.1(2)c Voltage regulation function " and through voltage management improvements. Assuming that the power sector emits 24,000kt of carbon dioxide, and after correcting the influence of the growth of electricity demand from 2014 till today, our estimate shows that if transmission loss is reduced by 0.01%, carbon dioxide emissions can be reduced by approximately 33.8kt/year.
7.3 Expected Benefits for Japan In the world of operational technology (OT), which has been a closed world in the past, the use of general-purpose products and standard protocols has been promoted for cost reduction, and connection to data processing systems (IT systems) has been driven for efficiency improvement. In the industrial arena, products and facilities sit at the center of business. The utilization of such information is essential and the combination of OT and IT would offer numerous benefits. Generally, the OT sector collects data from facilities to efficiently supervise/control the facilities based on this data. The IT sector prepares market forecasts and production schedules utilizing product sales and manufacturing information.
Electric power companies prepare facility expansion and repair plans based on data of the operational status of facilities as well as the status of electricity consumption. In other words, OT data sits at the center of the business of electric power companies, with SCADA sitting at the center of OT. It is expected that the combination of IT and OT and the introduction of IoT technology will be promoted in Bangladesh in the future. Introducing Japanese SCADA systems in Bangladesh would allow Japanese companies to enter into the center of OT in the country. This approach would help Japanese companies have more business opportunities and gain a competitive advantage in the country.
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7.4 Assessing Japanese Companies' Competitive Advantages Today, PGCB is lacking in power system operation technology and SCADA design technology. This is where Japan can find its business opportunity. By providing PGCB with technical assistance through training programs concerning the power system operation technology and SCADA design technology, which are demonstrating Japan’s high electric power quality, Japan will be able to get PGCB to fully recognize the competitive advantage of Japanese power system operation technology and the importance of cybersecurity measures. If PGCB reflects input from Japan in its SCADA procurement requirements and specifications, Japan can favorably promote Japanese market-oriented SCADA developed to satisfy the needs of partner countries, vs. overseas vendors that insist on product-oriented SCADA procurement.
7.5 Possible Utilization of Financing and Government Support From a financial standpoint, it is difficult for PGCB to implement this project on its own. Therefore, it is considered appropriate that Phase 1 and Phase 2, which were described in "6.3 Project Implementation Structure and Schedule" will be covered by ODA funds in a framework of technical cooperation, with Phase 3 covered by project loans.
7.6 Promoting this Approach to Other Countries It was confirmed that our proposal for this project is technically applicable to PGCB. With respect to the possibility of promoting this approach to other countries similar in economic growth to Bangladesh, another round of surveys for each country will be required, because the type of electric power system, scale, supervisory control system, electric power facilities, etc. vary depending on the country, and because the best supervisory control system and SCADA also vary depending on each country.
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Vietnam
Contents List of abbreviations ...... iv 1 Project Details ...... 1-1 1.1 Objectives of Project ...... 1-1 1.2 Project Details ...... 1-1 1.3 Project Implementation Method ...... 1-2 1.3.1 Project Implementation Structure ...... 1-2 1.3.2 Implementation Schedule ...... 1-3 2 Actual State of Investigated Country...... 2-1 2.1 Basic Information about the Country ...... 2-1 2.1.1 Economic Situation ...... 2-1 2.1.2 Economic Development Policies ...... 2-3 2.2 Power Overview ...... 2-3 2.2.1 Power Overview ...... 2-3 2.2.2 Power Policies ...... 2-4 2.3 Regarding Electric Power Circular ...... 2-5 2.3.1 Basic Structure of the Vietnamese Law ...... 2-5 2.3.2 Circular 25/2016/TT-BCT ...... 2-7 (1) Scope ...... 2-7 (2) Subjects of application ...... 2-7 (3) Main contents ...... 2-7 2.3.3 Circular 28/2016/TT-BCT ...... 2-9 (1) Scope ...... 2-9 (2) Subjects of application ...... 2-9 (3) Main contents ...... 2-9 2.3.4 Circular 39/2015/TT-BCT ...... 2-11 (1) Scope ...... 2-11 (2) Subjects of application ...... 2-11 (3) Main contents ...... 2-11 2.3.5 Circular 40/2014/TT-BCT ...... 2-14 (1) Scope ...... 2-14 (2) Subjects of application ...... 2-14 (3) Main contents ...... 2-14 2.3.6 Circular 44/2014/TT-BCT ...... 2-18 (1) Scope ...... 2-18 (2) Subjects of application ...... 2-18 (3) Main contents ...... 2-18 2.3.7 Circular 55/2017/QD-DTDL ...... 2-20 (1) Scope ...... 2-20 (2) Subjects of application ...... 2-20 (3) Main contents ...... 2-20 2.3.8 Circular 69/2018/QD-DTDL ...... 2-23 (1) Scope ...... 2-23 (2) Subjects of application ...... 2-23 (3) Main contents ...... 2-23
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2.3.9 Circular 03/2017/TT-BTTTT ...... 2-25 (1) Scope ...... 2-25 (2) Regulated entities ...... 2-25 (3) Main contents ...... 2-25 3 Current Situation and Prospects for Power Supply ...... 3-1 3.1 Power Supply Structure ...... 3-1 3.2 Overview of EVN SMART GRID PLAN ...... 3-2 3.3 Facility Enhancement Plan ...... 3-4 3.3.1 Plan of Total Installs Generation Capacity ...... 3-4 3.3.2 Plan of Transmission and Transformer ...... 3-5 4 Current situations of Power Control Operation and Control Facilities ...... 4-1 4.1 Operation ...... 4-1 4.1.1 Monitoring Control Organization ...... 4-1 4.1.2 Responsibility Border of Power System ...... 4-4 4.1.3 Operation ...... 4-6 (1) Monitoring Work ...... 4-6 (2) Operation work ...... 4-6 (3) Recording work ...... 4-8 (4) Data maintenance in SCADA ...... 4-8 4.2 Facility ...... 4-9 4.2.1 SCADA/EMS ...... 4-9 (1) Function configuration ...... 4-9 (2) Hardware configuration ...... 4-9 (3) Backup SCADA ...... 4-10 4.2.2 Communication Network ...... 4-10 5 Issues of Power Control Operation and Control Facilities Considering Future Facility Reinforcement ...... 5-9 5.1 Operation ...... 5-9 5.1.1 Monitoring Control Organization ...... 5-9 (1) Role sharing ...... 5-9 (2) Workload ...... 5-9 5.1.2 Operation ...... 5-9 (1) Operation work ...... 5-9 (2) Estimate of issues in EVN by comparison with TEPCO Power Grid ...... 5-10 (3) Recording work ...... 5-11 5.2 Facility ...... 5-11 5.2.1 SCADA/EMS ...... 5-11 (1) Hardware configuration ...... 5-11 (2) Application ...... 5-12 6 Investigation for Improving Work Schemes ...... 6-1 6.1 Operation ...... 6-1 6.1.1 Monitoring Control System ...... 6-1 (1) Review of Organization ...... 6-1 6.1.2 Operation ...... 6-2 (1) Creation of operation procedure ...... 6-2
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7 Benefits from Improvements in the Project ...... 7-1 7.1 Expected Benefits for the Partner Country ...... 7-1 7.1.1 Reducing in Transmission Loss...... 7-1 (1) transmission loss ...... 7-1 (2) Increase in transmission loss due to transmission line stoppage ...... 7-1 (3) Reduction of transmission loss by automating NLDC operation ...... 7-3 (4) Estimation of transmission loss reduction ...... 7-3 7.1.2 Reduction of Limitation for High-efficiency Thermal Power Plant ...... 7-4 7.1.3 Reduction of Power Outage Recovery Time ...... 7-4
7.2 Estimation of CO2 Emissions Reduction Amount ...... 7-5 7.3 Expected Benefits for Japan ...... 7-5 7.4 Assessing Japanese Companies’ Competitive Advantages ...... 7-5 7.5 Possible Utilization of Financing and Government Support ...... 7-6 7.6 Promoting this Approach to Other Countries ...... 7-6
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Abbreviations ABBREVIATION SIGNIFICANCE EVN Electricity of Vietnam MOIT Ministry of Industry and Trade of the Socialist republic of Vietnam NLDC National Load Dispatching Center RLDC Regional Load Dispatching Center HRM Human Resource Management Department SCADA Supervisory Control and Data Acquisition EMS Energy Management System E/O Emergency Outage S/O Scheduled Outage PLC Power Line Carrier OPGW Optical Ground Wire BSLDC Bulk System Load Dispatching Center PDP7 Power Development Plan 7
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1 Project Details 1.1 Objectives of Project Vietnam’s entire power grid, including all power generation, transmission, and distribution, has been owned, operated, and maintained by Electricity of Vietnam (EVN), which is a state-run power company. Its recent power generation area is in a competitive power generation market based on 03/2013/TT-BCT and 79/QD-DTDL. At present, Vietnam’s voltage classes are divided into three ranges: high voltages of 500kV, 220kV, and 110kV, medium voltages of 1kV to 35kV, and low voltages below 1kV. 500kV and 220kV are used for power transmission systems that connect the North, Middle, and South of Vietnam. 110kV is applied to power transmission/distribution systems in main supply areas, whereas 1kV to 35kV are applied to subordinate distribution systems. The total electricity generated in Vietnam is approximately 182,000GWh and its power facility capacity has reached approximately 40,000MW. Such figures are increasing year by year in Vietnam, which is a developing country. Vietnam’s power development plan is currently being implemented based on the 7th Power Development Plan (PDP7), which was reviewed by the government in March 2016. PDP7 describes the power development plan from 2011 to 2020 with an eye to 2030 and its objective is to achieve a total generated electricity of 572,000GWh and a power facility capacity of 129,500MW by 2030. The current power grid must be expanded in order to transmit and distribute such enormous amounts of electricity.
At present, EVN uses EMS/SCADA at a National Load Dispatch Center (NLDC) to monitor and control all of its substations (by telephone). As the power plants are enhanced and the systems are expanded, the current NLDC is expected to reach its organizational limits due to operational pressure, personnel shortage, etc. If the power plant capacity increases toward 2030, NLDC will be involved more deeply into the demand and supply management. Therefore, it is necessary to reform NLDC’s organization structure and establish a new mechanism for monitoring and controlling the power grid. In addition, regional load dispatching centers exist under LNDC and they are abbreviated as RLDCs. At present, there are three RLDCs in the North, Middle, and South. Although only these three are currently in operation, more RLDCs will need to be built for the power systems, as the power plants are enhanced and the number of substations increases in the future.
The purpose of this project is to investigate and analyze the monitoring and control organizations, operations, and SCADA of NLDC under EVN, and then further investigate the feasibility of introducing Japan’s high-quality operational technologies for power systems.
1.2 Project Details This project investigates the following items.
i. Background investigation a. Policy trends in the target country b. Strategy trends by the target company
ii. Collection of information required to introduce operational technologies for power
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systems a. Identification of the actual current state of the power infrastructure b. Identification of the needs and issues of the target company c. Current and future trends in the monitoring and control structure d. Personnel development structure
iii. Reduction/regulation of energy-originated CO2 emissions a. Identification of the current emissions b. Tentative calculation of the reductions achieved by introducing operational technologies for power systems
iv. Superiority check of Japanese companies a. Operational superiority evaluation
1.3 Project Implementation Method 1.3.1 Project Implementation Structure Figure 1-1 shows the structure used to implement this project.
Figure 1-1 Pre-FS Implementation Structure
The main entity that implements this project is TEPCO IEC, Inc. In addition, McAfee Co., Ltd. has cooperated in the present state analysis of the cyber security field and the business scheme examination, whereas NTT DATA Corporation has cooperated in the network investigation and analysis.
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1.3.2 Implementation Schedule Figure 1-2 shows the schedule for implementing this project.
Figure 1-2 Pre-FS Implementation Schedule
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2 Actual State of Investigated Country 2.1 Basic Information about the Country 2.1.1 Economic Situation Vietnam’s economy maintains continuous growth. As shown in Figure 2-1, the country’s GDP growth rate for the past 10 years is approximately 6.01% in average. It rose to 6.8% in 2017. According to a report released by the World Bank, it is expected to slow down to 6.6% in 2019, and then 6.5% in 2020. However, this will be part of the global trend. While such economic slowdown is predicted globally, Vietnam’s expected GDP growth rate exceeds 6.3%, which is the average level in the East Asia and Pacific Areas, and Vietnam is also expected to maintain a +4% rise by 2020.
References：JETRO Report https://www.jetro.go.jp/ext_images/world/asia/vn/data/vn_overview201811.pdf Figure 2-1 GDP growth rate of Vietnam
Figure 2-2 shows the sectoral share of GDP in Agriculture, Industry, and Service in 2017, and Figure 2-3 shows the trends in the share of Agriculture, Industry, and Service sectors in GDP. According to Figure 2-3, although the dramatic change has not been seen in each of the three sectors since 2010, Agriculture is gradually decreasing, indicating that the Service sector is increasing little by little.
GDP is closely related to electricity demand. Even in Japan, electricity demand was also increasing during the rapid growth period of GDP. Electricity demand is expected to grow in Vietnam as GDP growth can be expected in the future as well. Future forecast of electricity demand by MOIT is shown in Figure 2-4.
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References：VIET NAM ENERGY POLICY MINISTYR OF INDUSTRY AND TRADE General Directorate of Energy https://eneken.ieej.or.jp/data/6238.pdf#search='Vietnam+GWh
Figure 2-2 Sectoral Share of GDP at Constant Prices (2017)
References：VIET NAM ENERGY POLICY MINISTYR OF INDUSTRY AND TRADE General Directorate of Energy https://eneken.ieej.or.jp/data/6238.pdf#search='Vietnam+GWh
Figure 2-3 Trend of Structural Transformation of Sectoral Shares in GDP
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References：VIET NAM ENERGY POLICY MINISTYR OF INDUSTRY AND TRADE General Directorate of Energy https://eneken.ieej.or.jp/data/6238.pdf#search='Vietnam+GWh
Figure 2-4 Power consumption forecast
2.1.2 Economic Development Policies Vietnam maintains a high GDP growth rate of 6.01% in average over the past 10 years. Such economic growth was derived from the policies of "doi moi", which were declared in 1986. The policies of "doi moi” are based on the following four policies:
1. Introduction of capitalist economy 2. Cooperation with the international community 3. Investments into industries required for lives of the people 4. Mitigation of socialist policies
Based on the policies of “doi moi”, Vietnam extended the autonomy of companies, opened its economy to the world and introduced a market economy. In 2000, the country revised its foreign investment act to increase direct foreign investments into Vietnam in the fields of development and infrastructure improvement in Vietnam, sponsored by investment institutions and foreign-owned companies.
2.2 Power Overview 2.2.1 Power Overview As for power business operations in Vietnam, the Ministry of Industry and Trade (MOIT) is responsible for the power and energy field, the Ministry of Planning and Investment (MPI) is responsible for the national development planning and investment field, and the Ministry of Natural
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Resources and Environment (MONRE) is responsible for the environmental regulation field. Regulations on the electricity market and electricity charges are controlled by the Electricity Regulatory Authority of Vietnam (ERAV) immediately under MOIT. In addition, the Institute of Energy (IE) immediately under MOIT formulates energy policies, establishes power development plans and conducts power-related investigations and research. According to an investigation on EVN, EVN used to dominate the electricity market in Vietnam as the state-owned corporation, but the Ministry of Commerce and Industry officially decided to liberalize the electricity wholesale market. Currently, power generation business operators, including foreign-owned companies, are allowed to enter the market as Independent Power Producers (IPPs). While non-power generation businesses are vertically integrated by EVN, company split-up is taking place for liberalization. Figure 2-5 shows the power business structure of Vietnam.
Figure 2-5 Power Business Structure of Vietnam
The EVN group companies include companies that are wholly owned and directly controlled by EVN, self-financing companies, and JSCs (Joint Stock Companies) whose stocks are partially owned by EVN. Regarding the power generation businesses operated by the EVN group, its power plants were divided into GENCO1, GENCO2, and GENCO3 due to the impact of the competitive power generation market in June 2012. The directly-controlled companies, self-financing companies, and JSCs are under these three companies. VINACOMIN (Vietnam National Coal Mineral Industries Group) and PVN (Vietnam Oil and Gas Group) are operating power generation businesses as IPPs, for example.
2.2.2 Power Policies Vietnam’s power policies are described in the Power Development Plan (PDP). The PDP is a medium-term power development plan and reviewed once every five years or so. The PDP is prepared by MOIT as the main entity, in cooperation with IE, EVN, and other parties. Then, the prepared PDP is filed with the government/prime minister, and finally issued upon approval. The
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PDP contains a power master plan and vision along with their planning periods. The currently- issued PDP is PDP7, which is a revised version. PDP7 was originally issued in July 2011, and then revised in December 2013 and March 2016. The planning periods in the current PDP7 are as follows:
1. Planning periods: Power master plan: 2011 to 2020 Vision: Until 2030
2.3 Regarding Electric Power Circular 2.3.1 Basic Structure of the Vietnamese Law In Vietnam, the Constitution is a fundamental law and has the highest legal force. All legal norms must be in compliance with this law. In addition to the constitution and laws that the National Assembly of Vietnam has the right to establish, the main legal norms and the government organizations that have the right to establish those norms are in the following order.
(i) Constitution (ii) Law (iii) Resolution (Resolution of a national assembly) (iv) Ordinance (Ordinance of Standing Committee of the National Assembly) (v) Decree (Agreement of Government) (vi) Decision (Decision of Prime Minister) (vii) Circular (Circular of Ministries)
Basic structure of the Vietnamese law is shown in Figure 2-6. Among these, what has a relation to LNDC is Circular created by MOIT and the following eight Circulars exist.
(i) Circular 25/2016/TT-BCT (ii) Circular 28/2016/TT-BCT (iii) Circular 39/2015/TT-BCT (iv) Circular 40/2014/TT-BCT (v) Circular 44/2014/TT-BCT (vi) Circular 55/2017/QD-DTDL (vii) Circular 69/2018/QD-DTDL (viii) Circular 03/2017/TT-BTTTT
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Figure 2-6 Basic structure of law
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2.3.2 Circular 25/2016/TT-BCT Circular 25/2016/TT-BCT provides regulation of technical requirements and operation management of SCADA system.
(1) Scope The scope of the regulation of this circular (Circular 25/2016/TT-BCT) is shown below. 1. Requirements of operation of the electricity transmission system 2. Load forecasts 3. Transmission grid development plan 4. Technical requirements and procedures for connection to transmission grid 5. Assessment of electricity system security 6. Operation of electricity transmission system
(2) Subjects of application Subjects of application of this circular (Circular 25/2016/TT-BCT) are shown below. 1. Transmission network operator; 2. Electricity system and market operator; 3. Electricity wholesalers; 4. Electricity distribution units; 5. Electricity retailers; 6. Generating units; 7. Electricity customers receiving electricity from transmission grid (hereinafter referred to as “electricity customers”); 8. Vietnam Electricity; 9. Other organizations, individuals.
Note that Generating sets of a power plant with total installed capacity greater than 30 MW connected to distribution grid must meet technical requirements of equipment connected to transmission grid and other relevant requirements prescribed herein.
(3) Main contents a. Requirements in operation of transmission power system 1. Frequency 2. Voltage 3. Voltage fluctuation 4. Reliability of transmission network 5. Power loss of transmission network b. Load forecast 1. General provisions on forecasting electricity demand for the national electricity system 2. Monthly load forecast
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3. Weekly load forecast 4. Daily load forecast c. Development plan of transmission system 1. General principle 2. Details of development plan of transmission system d. Operation of power transmission system 1. Principle of power transmission system operation - Operation mode of the power transmission system - Operation of power transmission system - Troubleshooting handling - Security of the transmission system 2. Responsibility for the operation of power transmission system – Responsible for transmission system and market management – Responsibility of the power transmission unit - Responsibility of the power distribution unit 3. Maintenance of the power transmission system – General provisions on maintenance and repair of power transmission system – Maintenance and repair plan of transmission system 4. Adjustment, communication and reporting of operations – Communication in case of trouble
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2.3.3 Circular 28/2016/TT-BCT Circular 28/2014/TT-BCT provides the regulations on troubleshooting process in the national electricity system.
(1) Scope This circular provides principles and procedures of handling incidents to restore the country's power system to a normal operative system.
(2) Subjects of application Subjects of application of this circular (Circular 28/2016/TT-BCT) are shown below. 1. The national electricity system moderation unit (the national electricity system regulation center). 2. Generator unit. 3. Power transmission unit. 4. Power distribution unit. 5. Electricity distribution and retail unit. 6. Customers using electricity receive electricity directly from transmission grid, customers use distribution grid with own station. 7. Operators of units. 8. Other related organizations and individuals.
(3) Main contents a. Requirements and principles of handling national electric system incidents 1. Setting up the line of electric system - Principles for making basic wiring diagrams in the electricity system 2. Protection and automatic - Protection relay requirements when operating equipment 3. Requirements, principles and distribution of national electricity system treatment - General requirements for troubleshooting national electricity system - Principles of troubleshooting national electricity system 4. Handling wired incidents b. Handling wired incidents 1. Handling of troubleshooting on 500kV lines - Transmission limits on 500 kV lines 2. Handling of troubleshooting on lines over 35kV to 220kV - Handling of overloaded overhead lines, supplying voltage over 35 kV to 220 kV 3. Handling of troubleshooting on 35kV or lower lines – Handling of incidents on overhead lines supplying voltage at 35kV or less 4. Handling of troubleshooting power cables
2-9 c. Handling of troubleshooting such as at power stations 1. Handling troubleshooting at a power station 2. Handling troubleshooting of transformers - Restoration of transformers 1. Handling of troubleshooting of other devices 2. Full shutdown of the power station - Response by staff d. Handling of the warning, emergency and extreme emergency policy 1. Handling the warning mode - Warning regime 2. Handling the emergency mode - Emergency regime 3. Handling the extreme emergency mode - Extreme emergency regime e. Organization of implementation 1. Organization of implementation 2. Implementation effect
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2.3.4 Circular 39/2015/TT-BCT Circular 39/2015/TT-BCT provides regulation of technical requirements and operation management of SCADA system.
(1) Scope The scope of the regulation of this circular (Circular 39/2015/TT-BCT) is shown below. 1. Requirements in operating power distribution systems. 2. Forecast of electricity load demand. 3. Plan for investment in distribution grid development. 4. Technical conditions and requirements and procedures for connection to distribution grids. 5. Operating distribution electricity system.
(2) Subjects of application Subjects of application of this circular (Circular 39/2015/TT-BCT) are shown below. 1. Power distribution unit. 2. Electricity distribution and retail unit. 3. National electricity system regulation unit. 4. Power transmission unit. 5. Customers use distribution grid. 6. Vietnam Electricity Group. 7. Other relevant organizations and individuals.
(3) Main contents a. Operational requirements of power distribution 1. Technical requirements – Frequency - Voltage - Allowable current 2. Reliability of the power supply and power loss b. Load forecast of power distribution systems c. Plan for investment in power distribution systems 1. General provisions on planning for investment in power distribution systems 2. Details of plan for investment 3. Approval order of plan for investment d. Connection to power distribution systems 1. Principles – Information system requirements
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- Requirements for connecting SCADA system - Technical requirements of control center e. Operation of power distribution systems 1. Responsibilities for operation – Responsibilities for power distribution systems – Responsibilities for power distribution units 2. Operation plan – Operation of power distribution systems - Operation of power distribution systems in remote islands 3. Emergency operation - Operation in a case where a major accident occurred in 110kV power distribution system – Restoration of power distribution systems 4. Voltage control – Load control – Load reduction measures – Performing voltage adjustment - Monitoring and remote operation - Contact during operation - Notification when an incident occurs 5. Report on operation of power distribution systems f. Operation requirements for distribution 1. Technical requirements – Frequency - Voltage - Allowable current 2. Reliability of power supply and power loss g. Load prediction of distribution system h. Investment plan of distribution system 1. General provisions on investment planning of distribution system 2. Contents of investment plan 3. Approval process of investment plan i. Connection to the distribution system 1. Principle – Information system requirements - Requirements for connecting SCADA systems - Technical requirements of the control center j. Operation of distribution system 1. Responsibility in operation
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– Responsibility of the power distribution unit 2. Operation plan – Operation of distribution system - Operation of distribution system of remote island 3. Operation of Emergency - Operation when a serious accident occurs in 110 kV distribution system – Restoration of distribution system 4. Voltage control – Load control – Load mitigation measures – Voltage adjustment - Monitoring and Remote Operation - Contact in operation - Notification when an incident occurs 5. Report on operation of distribution system
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2.3.5 Circular 40/2014/TT-BCT Circular 40/2014/TT-BCT provides provisions on dispatching of the national power system. National power system is a power system uniformly directed nationwide. Dispatching is an output control of each power station by load dispatching or load-dispatching instruction.
(1) Scope The scope of the regulation of this circular (Circular 40/2014/TT-BCT) is shown below. 1. Dispatching hierarchy of the national power system; 2. Responsibilities of organizations and individuals involved in dispatching and operation activities of the national power system. 3. Planning and approval of operation mode of the national power system. 4. Dispatching and operation of the national power system in real-time. 5. Duties of divisions involved in dispatching of the national power system. Operation of the power plant, power station, power network, and control center. 6. Training of titles directly involved in dispatching and operation of the national power system
(2) Subjects of application Subjects of application of this circular (Circular 40/2014/TT-BCT) are shown below. 1. Vietnam Electricity Group. 2. National power system dispatching unit. 3. Power generating unit. 4. Power transmitting unit. 5. Power distributing unit. 6. Power retailing and distributing unit. 7. Customers receiving power directly from the transmission power network, customers using distribution power network with separate substation. 8. Operators of units. 9. Other relevant organizations and individuals.
(3) Main contents a. Dispatching hierarchy and right of dispatching level 1. Hierarchy, control authority, and inspection authority of the national power system as well as hierarchy of information grasping right - Dispatching hierarchy of the national power system - Principles of hierarchy of the control and inspection authority 2. CONTROL AUTHORITY, INSPECTION AUTHORITY AND INFORMATION GRASPING RIGHT - Control authority - Inspection authority of the superior dispatching level 3. Right of the national dispatching level - Control authority of the national dispatching Level
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- Inspection authority of the national dispatching Level 4. Right of the Regional dispatching level - Control authority of the regional dispatching level - Inspection authority of the regional dispatching level 5. Right of the provincial dispatching level - Control authority of the provincial dispatching level - Inspection authority of the provincial dispatching level 6. Right of the district distribution dispatching level - Control authority of the district distribution dispatching level - Inspection authority of the district distribution dispatching level 7. Right of the unit managing and operating power plant, power station and control center - Control authority of the power plant, power station and control center b. Levels of and responsibilities for the national power system 1. Responsibility of the dispatching levels - Responsibility of the national dispatching Level - Responsibility of the regional dispatching level - Responsibility of the provincial distribution dispatching level - Responsibility of the district distribution dispatching level 2. Responsibility of the district distribution dispatching level - Responsibility of the power generating units - Responsibility of the power transmission units - Responsibility of the power distributing units - Responsibility of the power retailing and distributing units - Responsibility of the telecommunications services providers - Responsibility of the gas suppliers for power generation c. Operation mode of the power system 1. Registration and approval of the operation mode of the power system - Main contents of the operation mode of the power system - Approval of the operation mode of the power system 2. Development of the operation mode of the power system - Basic one-line diagram of the power system - Forecasting of the power load demand
d. Dispatching and operation of the national power system in real time 1. General provisions - Contents of the dispatching instructions - Form of the dispatching instructions - Requirements for compliance with dispatching instructions - National dispatching Level - Regional dispatching level - Provincial distribution dispatching level - District distribution dispatching level - Working relationship in dispatching and operation of the power system
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- Report on daily operation and breakdown 2. Operation shift regulation - Regulation on shift handover and acceptance - Regulations for operator during shift duty 3. Frequency control - Measures of frequency - Limit of voltage - Regulation on voltage adjustment 4. Power network control - Automatic power network control - Outage of lines and electrical equipment 5. Power source control 6. Load control - Notification of the control of non-emergency usable capacity - Dispatching instructions on control of the emergency usable capacity - Breakdown load switching due to shortage of the power source as per dispatching instruction - Automatic load shedding under low frequency - Load switching due to overloading or low voltage 7. Breakdown troubleshooting - Breakdown troubleshooting of the power system e. Duties of divisions directly involved in dispatching and operation activities of the national power system 1. National dispatching level - Divisions directly involved in dispatching activities of the national power system - Duties, powers and responsibilities of the national dispatcher 2. Regional dispatching level - Divisions directly involved in dispatching activities of the regional power system - Regulations on employees of the regional dispatching division on duty - Duties, powers and responsibilities of the regional dispatchers 3. Provincial distribution level - Divisions directly involved in dispatching activities of the distribution power system - Responsibilities, powers and responsibilities of the provincial distributing dispatchers 4. District distribution dispatching level 5. Operators at the power plants, power stations and control centers f. Training of the titles directly involved in dispatching and operation of the national power system 1. General provisions - Training of the operator at dispatching levels 2. Training at national power system - Regulation on new training for the national dispatchers - Regulation on re-training for the national dispatcher
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- Regulation on training of the power system planning and analysis engineer for the national power system - Regulation on training for the SCADA/EMS engineer of the national power system 3. Training at the regional dispatching level - Regulations on new training for the regional dispatcher - Regulation on re-training for the regional dispatcher - Regulation on training for the power system planning and analysis engineer of the regional power system - Regulation on training for the SCADA/EMS engineer of the regional power system 4. Training at provincial distribution dispatching level - Regulation on re-training for the provincial distributing dispatcher - Regulation on training for the engineer of the distribution power system - Regulation on training for the SCADA/DMS engineer of the distribution power system 5. Training at district distribution dispatching level - Regulation on new training of the district distributing dispatcher - Regulation on re-training for the district distributing dispatcher 6. Training at the power plant, power station and control center
g. Implementation organization 1. Implementation organization 2. Effect
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2.3.6 Circular 44/2014/TT-BCT Circular 44/2014/TT-BCT provides the regulations of working process in the National electric system.
(1) Scope The regulation of this circular (Circular 40/2014/TT-BCT) describes the order in which work is conducted.
(2) Subjects of application Subjects of application of this circular (Circular 44/2014/TT-BCT) are shown below. 1. National electricity system regulation unit. 2. Generator unit. 3. Power transmission unit. 4. Power distribution unit. 5. Electricity distribution and retail unit. 6. Customers using electricity receive electricity directly from the transmission grid, customers use the distribution grid with their own station. 7. Operators of the units. 8. Other related organizations and individuals.
(3) Main contents a. Order to work 1. Action organization - General requirements on manipulating electrical equipment in the national electricity system - Verbal manipulation order (order by phone) - Operation procedure table - Creation and approval of stop plan - Creation and approval of unexpected operation procedure - Operation records 2. Execute action - Requirements for the manipulation commanders - Performing operations involving secondary circuits - Manipulation during high demand for the electricity and shift delivery - Manipulate in bad weather conditions - Suspend operation 3. Action - General provisions of remote operation - Conditions of remote operation b. Regulation of basic activities
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1. Action device close cut – Disconnection operation 2. Workshop transformer - Power cut operation of the transformers - Operation of the transformers 3. Line working - Operation of the power cut off lines 4. Bars action – Operation of the busbar 5. Working other electrical devices c. Number of devices in the national electric system 1. General principles - Rules on naming and numbering of devices
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2.3.7 Circular 55/2017/QD-DTDL Circular 55/2017/QD-DTDL provides technical requirements and operation management of SCADA system.
(1) Scope The regulation of this circular (Circular 55/2017/QD-DTDL) covers technical requirements, signal connection, and operation management of SCADA system in electrical system.
(2) Subjects of application Subjects of application of this circular (Circular 55/2017/QD-DTDL) are shown below. 1. The electricity system and market operating unit (National Electricity Moderation Center). 2. Power transmission unit. 3. Power distribution unit. 4. Electricity distribution and retail unit. 5. Power generation unit. 6. The channel operator. 7. Customers use electricity to receive electricity directly from the transmission grid. 8. Customers use distribution grid with separate transformer station. 9. Vietnam Electricity Corporation. 10. Other relevant organizations and individuals. Other related organizations and individuals.
(3) Main contents a. General technical requirements of the SCADA/EMS/DMS system 1. Technical requirements of the SCADA system - General requirements for manipulating electrical equipment in the national electricity system. - Technical requirements of the SCADA system - Basic components of the SCADA system in electrical system - Configuration and function of the central SCADA system - Requirements for connection, data sharing and network security 2. Technical request of the SCADA/EMS system - System structure of the SCADA/EMS - Application of the EMS system 3. Technical requirements of the SCADA/DMS system - Configuration of the SCADA / DMS system - Application of the DMS system 4. Request engineering communication channel system - General requirement - Speed of the data transmission channel - Interface for connecting channels - Communication protocol
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5. Technical requirements for the RTU terminals/Gateway - General technical requirements - Technical requirements for the RTU equipment - Technical requirements for the Gateway equipment - Technical requirements for the converters A b. SCADA system connection in electric system 1. Register to the SCADA system connection for electric factory and transformers - Registration of the connection - Technical design agreement - Registration of the End-to-End inspection - Examination and acceptance of the End-to-End 2. Register SCADA connections for the power plant and improved pressure palaces - Registration for the renovation or expansion of the RTU / Gateway terminals - Technical design agreement for cases of renovation or expansion of the RTU/Gateway terminals - End-to-End inspection registration for cases of renovation or expansion of the RTU/Gateway terminals - Checking End-to-End for cases of improving or extending the RTU/Gateway terminals 3. Content test point-to-point and end-to-end testing - Contents of checking and acceptance of Point-to-Point from the RTU to the electrical equipment - Contents of acceptance testing of Point-to-Point from the SAS/DCS system to the Gateway computers - Contents of checking and acceptance of the transmission channels - Contents of checking and acceptance of the End-to-End c. MANAGEMENT OF OPERATION OF THE SCADA/EMS/DMS 1. Responsibilities of participants and operation system of the SCADA/EMS/DMS - The responsibility of the Regime has control - Responsibilities of the operation management units - Responsibilities of the channel operator 2. SCADA DATA LIST - Requesting the SCADA data list of the power plant - Requesting the SCADA data list of the substation - Request for the SCADA data list of the Control Center 3. Handling of incidents in the SCADA system operation - General principles - Troubleshooting central SCADA system - Troubleshooting RTU / Gateway terminals and transmission channels d. Appendix 1. Chart for connecting and registering a new power station and transformer. 2. Table of the SCADA data list 3. Testing into channel
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4. Test of the point-to-point 5. Collection test of the end-to-end
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2.3.8 Circular 69/2018/QD-DTDL Circular 69/2018/QD-DTDL provides procedures for issuance of certificates of regulations on and operations of the national power system and inspection thereof by the electricity regulatory authority.
(1) Scope The regulation of this circular (Circular 69/2018/QD-DTDL) covers training, inspection, and issuance of certificates for operators at all levels at power stations, transformer stations, and control centers and includes the following. 1. Conditions for people appointed to training positions to directly participate in the work of moderation and operation. 2. Content of training for the titles to directly participate in moderation, operation at all levels and operating management units. 3. Procedures for inspection and certification of operation certificates. 4. Managing and using Operation Certificates.
(2) Subjects of application Subjects of application of this circular (Circular 69/2018/QD-DTDL) are shown below. 1. Vietnam Electricity Corporation. 2. National electricity system regulation unit. 3. Generator unit. 4. Power transmission unit. 5. Power distribution unit. 6. Electricity distribution and retail unit. 7. Customers using electricity receive electricity directly from the transmission grid, customers use the distribution grid with their own power station. 8. Operating staff. The channel operator. 9. Electric project investor.
(3) Main contents a. Training conditions and contents/Direct participles/National electricity control and operation 1. Training participatory lists/Direct conditions at the national level - Conditions for participating in trainings at the national level. - Outline of training types - Content of training for engineers of the national electricity system. - Content of training for SCADA/EMS engineers of the national electricity system. - Training programs at the national level. 2. Training list - Conditions for participating in trainings at the domain level. - Content of training for engineers of the regional power system. - Training programs at the domain level.
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3. Training distribution district - Conditions for participating in trainings at the district power distribution level. - Content of training concerning the district power distribution companies. - Content of training for engineers of the district power distribution system. - Content of training concerning SCADA/DMS of the district power distribution system. - Training programs at the district power distribution level. b. Inspection and grant of the operation certification 1. Responsibilities of the units - Responsibilities during test period 2. To get a certificate of operation - Items of certificate - Conditions of inspection 3. Content, form and assessment of the test results - Content of test - Form of test - Assessment of test results 4. Organization of inspection and granting of the operation certification - Organization of inspection - Announcement of results and issuance of the operation certificates c. Management, classification and use of the operation certification 1. Types of operation certificates - Operation certificate form - Grant of certificate 2. Management and use of operation certificate - Usage term of operation certificate - New level of operation certificate - Re-issuance of operation certificates - Management and use of operation certificates d. Appendix 1. Form of operation certification
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2.3.9 Circular 03/2017/TT-BTTTT Circular 03/2017/TT-BTTTT provides regulation of technical requirements and operation management of SCADA system.
(1) Scope This Circular regulates the security of information system by classification, including: guide the classification of information system by class; request the security of information system by classification; inspect and evaluate the security of information; keep and verify the proposal for the classification; report and share information.
(2) Regulated entities The entities regulated by this Circular are specified in Article 2 of the Government’s Decree No. 85/2016/ND-CP dated July 01, 2016 on the security of information system by classification (hereinafter referred to as Decree No. 85/2016/ND-CP)
(3) Main contents a. Guideline for the determination and classification of information system - Determination of specific information system b. Requirements for security of information systems by classification - General requirements c. Inspection and assessment of information security - Contents and forms of inspection and assessment d. Receipt and verification of the classification proposal - Submission and receipt of the classification proposal
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3 Current Situation and Prospects for Power Supply 3.1 Power Supply Structure EVN’s organization is structured as shown in Figure 3-1.
References : EVN annual report 2017 Figure 3-1 Organization Chart
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3.2 Overview of EVN SMART GRID PLAN 1. Objectives Objectives of Smart grid development - Enhancing the stability and reliability of power system - Increasing the productivities - Reduction of the technical and commercial loss - Reduction of the peak load - Reduction of electric system reliability indices (10-20% per year) - Better information for management - Improvement of customer satisfaction
2. Dispatching section 1. New SCADA/EMS project - Scope of project: modernizing National Load dispatching centre and 3 Regional load dispatching centers and 1 backup center in order to implement EMS at 2016 - Bidder: OSI – USA - The project implementation period: 12/2012 – 3/2015 - Status: ongoing
2. Fault recorder and PMU project (2 phases) - Scope: Purchasing and installing Fault recording equipment at 73 substations (500/220kV substations and power stations) - The project implementation period: 2014 – 2015 - Status: Project initiation document has been submitted
3. International Consulting Services - Scope: Evaluation, analysis and propose solution for enhancing the stability and reliability of Vietnamese power system - The project implementation period: 2014 – 2015 - Status: Project initiation document has been submitted
3. Transmission section 1. Upgrading substation control system projects - Scope of projects: Replace the traditional substation control panels by Computerized control system at the 500/220kV substations - The project implementation period: 2014 – 2016 - Status: PDO submitted to WB (TEP – Transmission Efficiency Project) 2. Remote control center projects - Scope: Set up remote control systems at substations and from there can control remotely about 5 – 10 substations around (without operators) - The project implementation period: 2014 – 2016 - Status: TEP - Scope of projects: Replace the traditional substation control panels by Computerized control system at the 500/220kV substations
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4. Distribution section 1. SCADA/DMS and 110kV substations without operators in EVNSPC - Scope of projects: Scope of projects: Replace the traditional substation control panels by Computerized control system at the 500/220kV substations - The project implementation period: 2012 – 2015 - Status: Bid document submitted to WB (DEP – Distribution Efficiency Project) 2. Upgrading SCADA/DMS in EVNHCMC - Scope: Upgrade the existing SCADA/DMS system in Ho Chi Minh City - The project implementation period: 2014 – 2015 3. Status: Project initiation – DEP Upgrading SCADA/DMS in EVNHCMC - MiniSCADA/DMS in Gia Lai and Quang Nam province (EVNCPC) - The project implementation period: 2014 – 2015 - Status: PDO submitted to Finland ODA 4. DAS Pilot project in Ho Chi Minh City - Scope of projects: Installing DAS for 2-4 MV lines (including many MV/LV substations, Recloses) - The project implementation period: 2013 – 2015 - Status: Japanese sponsor - TEPCO 5. AMI Pilot project in Ho Chi Minh City - Scope: AMI system with 48.000 smart meters in Ho Chi Minh City - The project implementation period: 2014 – 2015 - Consultant: AF Mercados – Spain - Status: Project initiation – DEP 6. AMR projects - Scope: Power companies invest many AMR projects (many phases) in order to install millions of electronic meters (PLC, GPRS, RF…) - The project implementation period: 2011 – 2017 - Status: ongoing
5. Renewable energy integration - Scope of projects: installing a solar and wind generation (4,500 W) in a smart building connected to LV network in Da Nang (EVNCPC – Central Power Corporation) - The project implementation period: 2013 – 2014 - Status: Project initiation submitted
6. Challenges - Lack of experiences - Choosing “Right” Smart Grid solutions - Integrating multi vendors’ products into unique system - Integration AMR and AMI - New jobs and retraining reduced employees - Enterprise change: Organization restructure, Rules, Business procedures… - Project Budgeting: Estimated cost for Smart Grid is about 2 bil. USD (exclude AMI investment: 4 bil. USD)
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3.3 Facility Enhancement Plan 3.3.1 Plan of Total Installs Generation Capacity Figure 3-2 and Table 3-1 show target increases in EVN’s power generation capacity by power plant type toward 2030, based on PDP7.
References：Ministry of Industry and Trade General Directorate of Energy Viet Nam’s Power Development Plan
Figure 3-2 Graph of Total installs capacity to 2030
Table 3-1 Table of Total installs capacity to 2030
References：Ministry of Industry and Trade General Directorate of Energy Viet Nam’s Power Development Plan
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3.3.2 Plan of Transmission and Transformer Figure 3-3 shows EVN’s enhancement plan for the length of transmission lines and capacity of transformers 500/220kV toward 2030.
References：Ministry of Industry and Trade General Directorate of Energy Viet Nam’s Power Development Plan
Figure 3-3 Transmission Network Investment Plan
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4 Current situations of Power Control Operation and Control Facilities 4.1 Operation 4.1.1 Monitoring Control Organization EVN NLDC is a subsidiary of Vietnam Electricity and has eight divisions with Board of Directors as well as the Division Center located in the northern, southern, and central areas in Vietnam as shown in Figure 4-1 and Figure 4-2.
Figure 4-1 Company Structure of NLDC(Reference:EVN NLDC Webpage)
Figure 4-2 Load Dispatching Organization Structure (Reference:EVN NLDC Webpage)
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Also, EVN NLDC has an organization called Load Dispatching Center (LDC) responsible for control of power generation and monitoring control of power system, which is decentralized and operated into four groups as separate organizations from the business organization structure of EVN NLDC. National Load Dispatching Center (NLDC) has control over the bulk system (500kW) throughout Vietnam. Regional Load Dispatching Center (RLDC) is divided and placed into three areas: northern area, southern area, and central area in Vietnam.
Responsibilities of each hierarchy are shown in Table 4-1.
Table 4-1 the Roles of Each Load Dispatching Center Division Responsibility National Load 1. Control of frequency of national power system Dispatching 2. Control of voltage on 500 kV Center 3. Control of capacity of generating units of large power plant 4. Switching and handling of breakdowns of 500 kV 5. Black start and restoration of 500 kV 6. Control of load of national power system 7. manage of breakdown of large power plant 8. reservoir of hydroelectric sources 9. Sets up the basic operation mode 10. Performs calculation and inspection upon requirement for operation (operation modes, setting form of automatic and protective relay on 500kV, parameters (short circuit power, short circuit currents), stability, load shedding) 11. Analysis and identification of cause of breakdowns on 500 kV 12. Management of operation of SCADA/EMS system 13. Aggregation of actual operation and report
North 1. Complies with the direction of the national dispatching Level Regional Load 2. Control of voltage Dispatching Center 3. Control of frequency in case of separation South 4. Control of capacity of generating units Regional Load Dispatching 5. -Switching and handling of breakdowns Center
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Central 6. Black start and restoration Regional Load 7. Coordination with the relevant regional dispatching level upon switching Dispatching and handling of breakdown of inter-region transmission lines Center 8. Notification regarding affecting the normal operation mode 9. Control of load 10. Registers the estimated operation mode with the national dispatching Level 11. calculation and inspection as per the operational requirement (operation modes, setting form of protective relay (220 kV, 110 kV), parameters (short circuit power, short circuit currents), automatic relays on distribution power network, protective and automatic relays of equipment on distribution power network) 12. evaluating the effect of connection of new power works 13. -setting and operation of automatic load shedding system under the frequency and voltage 14. analysis and identification of cause of breakdowns 15. Manages the operation of SCADA/EMS system 16. Makes the prescribed aggregation of regional power system and report
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Provincial 1. Complies with the direction of regional dispatching level Load 2. Control of voltage Dispatching Center 3. Control of frequency in case of separation 4. Control of capacity of generating units 5. Switching and handling of breakdowns 6. Restoration of distribution power system 7. Control of load 8. Coordination with relevant provincial distribution dispatching level upon switching of lines 9. Notification regarding affecting the normal operation mode 10. Notification of cause of breakdown to customers 11. Registers the estimated operation mode with the regional dispatching level 12. calculation and inspection as per the operational requirement (operation modes, setting form of protective and automatic relay, calculation, inspection and approval for setting values for protective equipment of relay) 13. power loss and recommendation of measures to reduce the power loss 14. setting and operation of automatic load shedding system under the frequency 15. Analysis and identification of cause of breakdowns 16. Management of operation of SCADA/DMS system, automation system 17. Aggregation, report and provision of data as required by the regional dispatching level
4.1.2 Responsibility Border of Power System EVN NLDC shares roles of system operation by voltage level and region. NLDC (one place) has a responsibility for 500kV system throughout Vietnam and RLDCs (three places) have responsibilities for each region of 220K to 110kV. Figure 4-3 shows the division of roles by voltage class and Figure 4-4 shows an overview of the areas divided by Load Dispatching Center.
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Figure 4-3 Assigned roles by voltage class
Figure 4-4 Assigned area of each Load Dispatch Center
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4.1.3 Operation (1) Monitoring Work Basically, Load Dispatching Centers acquire information of the substation controlled by them and remotely monitor the state of the facilities through SCADA. All information of the substations which NLDC and RLDC from A0 to A3 use are linked with each other by SCADA system, so each of NLDC and RLDC can acquire information of circuit breakers and switchgears as necessary.
(2) Operation work Operations can be performed on facilities in the control area divided by voltage class and area according to each plan and judgment, but since the power systems are electrically connected to each other, a rule prescribed based on the dispatching hierarchy is applied to planning, creation of operation procedures, instruction of operations, execution of operations, and use of record reports. As a method for performing operations, the procedures are prescribed in Circular strictly. Details are as follows. a. Order by phone a) The commander must clearly state their full name b) The commander must specify the name and title of the order recipient. c) Operation orders must be recorded and fully recorded in the operation diary at the units. d) Operation instructions must be short, clear, accurate and specify the purpose of the operation. e) The operator must understand the sequence of all expected operation steps, the conditions that allow it to follow the actual diagram status and the device operation mode. f) In case of forecasting, when it is impossible to communicate with mobile operators, allowing to order and manipulate multiple operational tasks at the same time. Mobile work. g) When ordering, the commander must ask the receiver to compare and adjust the time according to the clock of the commander. h) The order commander must repeat the command, record the operation command, and the commander's name and the time of the operation request. i) Only when the commander determines that it is absolutely correct and allows the operation to be performed, the receiver will then be able to perform the operation. j) The finishing operation must record the end time and report back to the commander. b. Remote operation There are no provisions related to specific operation rules for performing remote operations. Securing of the soundness of SCADA, communication line, and remote terminal unit which enables remote operations is prescribed. c. Creation of operation procedure The operation procedures have a prescribed format and contain the following subjects. They are applied through examination and approval processes when operation is implemented.
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A) Name of operation card B) Writer, Examiner, Approver C) Operator(commander) D) Purpose of the operation E) Intended time F) Conditions required for proceeding G) Operation item sequence H) Signature
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(3) Recording work A) Record and report of daily operation result (Report on daily operation) Reporting of the operation result is performed every day. The report line is in Figure 4-5.
Figure 4-5 Report line (Original)
Report data collected from the whole country is collected at NLDC. A person in charge of the report in NLDC collects the data by making use of Excel macro with the dedicated personal computer.
Regular report to general executives at EVN headquarters - NLDC reports on power generation and a demand forecast to the business meeting attended by the general executives at EVN headquarters and the top managers of the subsidiaries which is held every week.
(4) Data maintenance in SCADA For data maintenance in SCADA, NLDC retains engineers as SCADA Development Team and performs data change works and tests whenever data maintenance works are required due to such as construction of a new substation or transmission line.
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4.2 Facility 4.2.1 SCADA/EMS The current SCADA/EMS is called the fourth generation SCADA and adopts the SCADA/EMS made by the OSI in the United States. NLDC and RLDCs in three areas are introduced at the same time.
(1) Function configuration Table 4-2 shows the main functions of SCADA.
Table 4-2 Main functions of SCADA(Original) FUNCTION NAME DESCRIPTION SCADA Server The real-time applications Security Server Virus check and extermination for Virus Historian Server Retrieves real-time data from the front end processor Development Server Engineering for SCADA data Front End Processor Scanning, Monitoring & Receiving of field data from RTU Training Server Training simulation function Planning Server Generation planning Data Acquisition Server Acquiring and referring from RTU data Terminal Server Protocol Converting
(2) Hardware configuration Servers are arranged in the function unit and each server has dual configuration. Also, the LAN configuration is grouped by function and consists of System LAN, RTU LAN, Management/Engineering LAN, SCADA system LAN, Maintenance LAN, and Training LAN. It is also assumed that all physical units such as Ethernet switch, a firewall, and a network interface of each server has the dual configuration. It is assumed that a hot standby configuration and a cold standby configuration are used for the operating state of the dual-redundant servers, Ethernet switches, and firewalls according to the importance (required reliability). As for data exchange between servers belonging to different LAN classification, the servers are connected in a star form by a Layer 3 switch which is installed in the center of the LAN configuration. Connection among LAN segments are achieved by routing configuration. Thus, the network is logically divided. Therefore, servers cannot connect to the functionally irrelevant LAN. When the communication specification adopts a serial protocol, information transmission between the remote terminal unit installed in the substations/power stations and SCADA is achieved by establishing a connection via the terminal server in SCADA and converting the serial protocol to the Internet protocol or inversely converting the Internet protocol to the serial protocol. When the remote terminal units in the substations/power stations support the Internet protocol, they are connected directly with SCADA RTU LAN by the Layer 3 switch nearest to SCADA through Ethernet network called RTU WAN. Information from the the remote terminal units is language- or format-converted by a server called Front End Processor as data available inside SCADA. The office side has the Office LAN connected with SCADA and the Management HMI with which the management and the engineers of NLDC can check the operation state of the power system and the state of SCADA in real-time.
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A physically block able unit that can shut down the Ethernet line is installed on the route from the Management/Engineering LAN, Maintenance LAN, and Training LAN to the Layer 3 switch installed at the center place. Therefore, the state of a degeneration function operation can be set to protect SCADA by limiting to the monitoring control function when an incident caused by a cyber-attack and the like occurs.
(3) Backup SCADA Each of NLDC and RDLCs in three areas has a backup SCADA in place. The basic specification is the same except that the simulator function is not implemented.
4.2.2 Communication Network EVN NLDC connects NLDC, RDLCs and substations/power stations by using a wide area communication network owned by EVN. The outline is shown in Figure 4-6.
RTU
A0 A1
RTU A3 A2
RTU
A0=National Load Dispatching Center, A1=North Regional Load Dispatching Center, A2=South Regional Dispatching Center, A3=Central Regional Load Dispatching Center Figure 4-6 Image of connection between RTU and each Load Dispatching center
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5 Issues of Power Control Operation and Control Facilities Considering Future Facility Reinforcement 5.1 Operation 5.1.1 Monitoring Control Organization If the substation increases in future, the Monitoring Control Organization is expected to reach its limit. The reasons are explained below.
(1) Role sharing As facilities increase, workload for adjusting the supply/demand (adjusting amount of power generation) and operating the transmission system in NLDC is expected to increase. The details are described in later, but operations of system control increase proportionally to the facility reinforcement. Also, because the generator is planned to be added more, complexity of the supply and demand adjustment is expected to increase. Therefore, it is assumed that the roles of NLDC become excessive.
(2) Workload During day-to-day equipment operation in the substation, operation orders by a telephone are conducted as described in "4.1.3(2)a" and time to confirm the caller's name, title, and order details and to mutually repeat them to prevent inconsistency in the operation is required. The operation order takes much time. When operation amount increases with the expansion of the power system in future, operations ordered by a telephone become a bottleneck, and there is a possibility that the required operation amount cannot be handled. Dispatchers become unable to concentrate by tight situation of operation works, and human errors are expected to increase due to deterioration of accuracy of the operation order or omission of the required confirmation work. It may cause a false outage or a fatal accident. As a result, it is expected to cause deterioration of the electric power quality in the whole Vietnam.
5.1.2 Operation (1) Operation work As shown in Power Development Plan 7, there is a plan to further expand the transmission system in future in Vietnam. Consequently, it is expected that the amount of facilities will increase, and periodic inspection, facility repair, new facility construction works will rapidly increase. In that case, it is expected that troubles such as not being able to stop a facility may occur due to limitations of operation works. There is a concern that inspection time cannot be secured because the operational error occurs by operational congestion of NLDC operators and the operation is delayed and securing work safety may be neglected. This is a concern to be linked directly with deterioration of the electric power quality.
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(2) Estimate of issues in EVN by comparison with TEPCO Power Grid a. Estimate of operation amount in EVN based on system operation record in TEPCO PG Table 5-1 compares the facility scale between EVN and TEPCO Power Grid. The facility scale of EVN has already exceeded that of TEPCO Power Grid on data as of 2018. It is supposed that this is due to the difference of geographical conditions and that the transmission line to supply power to broader area becomes longer and the number of 220kV substations for regional grid systems increases. EVN is assumed to perform the monitoring control of large-scale transmission systems equivalent to or larger than TEPCO PG. As such, EVN plans to continue to expand the power system.
Table 5-1 Basic Quantity Comparison Basic Quantity EVN (July,2018) TEPCO PG (2017) 500kV Transmission Line 7503km 4520km 220kV (275kV Transmission Line 16920km 2339km 500kV Substation 28 SS 28 SS 220kV(275kV) Substation 114 SS 51 SS Dispatching Area 331,200 ㎢ 32,420 ㎢
The number of the system operations also increases with expanding the power system. Figure 5-1 estimates the planned outages based on total capacity data of transformers of 220kV or more in EVN which are installed/planned in Power Development Plan 7. According to Power Development Plan 7, it is expected that the capacity of the transformer will increase 3.3 times by 2030 compared to that in 2015. The transmission system in Vietnam in the stage of growth is in a phase where new facilities are installed for the present. In the future, when entering in a phase where the facilities are maintained, it is expected that inspection, repair, and update works of the facilities will increase, and operations of the system control will rapidly increase. According to the simulation result, it is expected that planned outage operations in 2025 will occur 3.3 times compared to that in 2015 and the number of operations in the system control will rapidly increase. The actual number is expected to exceed this number because this index does not include inspections/repairs of transmission lines, control devices, and switchgears.
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Estimation of Planned Outages 600000 8.00
7.00 500000 6.67 6.00 400000 5.15 5.00
300000 4.00 3.30 3.00 200000 1.93 2.00 100000 1.00 1.00 0.30 0 0.00 2010 2015 2020 2025 2030 2035
Total Capacity Deploy Outage Index
* Calculation of outage index: indexing the number of planned outages occurred, assuming that a life cycle of the transformer is 40 years, and a stop operation occurred during operation period is one for new construction, two for inspection, one for repair, and one for update. Figure 5-1 Estimation of Planned Outages
(3) Recording work In NLDC, power supply performance is reported to the EVN management weekly based on report from RLDC and NLDC operator. In the result of a hearing, there is a comment saying that there is a feeling of work burden. If the work of manual record reporting is continued, the amount of information to be recorded will increase due to the expansion of the power system. Then, unless the staff is increased or the operations are reviewed, it is concerned that the amount may exceed the range that operators in RLDC and NLDC can handle.
5.2 Facility 5.2.1 SCADA/EMS (1) Hardware configuration With respect to an inside configuration of SCADA, signals to be processed in real time, such as a signal for transmitting ON/OFF information of switchgears or the measured values collected from substations to operators and a signal for transmitting a control signal to local facilities, flow in the LAN. In addition, signals that do not require real-time processing as much as those signals described above, such as a signal for creating, saving, and calling an operation procedure, a signal for saving record in an archive, and a signal for processing a system calculation, also flow in the LAN. In the current architecture, all signal is exchanged via SCADA LAN. In the future, as the number of substations increases, the amount of information to be handled in NLDC will also increase. As such, the traffic in SCADA LAN also increases and a processing speed may become slow. Therefore, by
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separating the important signals requiring real-time processing from the other signals, it is necessary to create a mechanism for preventing the delay of such important signals.
(2) Application According to the estimation of the future workload in the system control in NLDC using TEPCO PG as an index, in NLDC, their operation works are assumed to become excessive and the required planned outage cannot be handled. Therefore, measures to automate the operators' works are required.
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6 Investigation for Improving Work Schemes 6.1 Operation 6.1.1 Monitoring Control System (1) Review of Organization It is optimum to divide NLDC's responsibilities because the future reinforcement of the power generation and transmission facilities causes increase of the workload in NLDC. NLDC currently deals with both supply-demand control operation and system control operation. By separating the system control operation from NLDC, they will be able to focus on the supply- demand control operation only. Therefore, dividing responsibilities for the system control has an advantage to achieve a high value-added operation.
Figure 6-1 Advantage of NLDC Reorganization
The role sharing between BSLDC, which is to be newly established, and NLDC is shown in Table 6-1. They are organized based on the existing role of NLDC.
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Table 6-1 Role sharing between BSLDC and NLDC National Load Dispatching Center Bulk System Load Dispatching Center 1. Control of frequency of national power 1. Control of voltage on 500 kV system 2. Switching and handling of breakdowns of 500 2. Control of capacity of generating units of kV large power plant 3. Control of load of national power system 3. Black start and restoration of 500 kV 4. Sets up the basic operation mode 4. manage of breakdown of large power 5. Performs calculation and inspection upon plant requirement for operation (operation modes, 5. reservoir of hydroelectric sources setting form of automatic and protective relay 6. Management of operation of EMS on 500kV, parameters (short circuit power, function short circuit currents), stability, load shedding) 7. Aggregation of actual operation and 6. Analysis and identification of cause of report breakdowns on 500 kV 7. Management of operation of SCADA function 8. Aggregation of actual operation and report
6.1.2 Operation In this section, for solving the operator shortage, possibilities for automating works in operations by SCADA are considered.
(1) Creation of operation procedure It is expected that operators' works increase due to progress of future facility reinforcement and occurrence of periodic inspections and repair works. Since the planned facility outage is a typical procedure, it is expected to be created automatically in some degree. Therefore, operators' works can be reduced by automating such a typical procedure using SCADA/EMS.
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7 Benefits from Improvements in the Project 7.1 Expected Benefits for the Partner Country 7.1.1 Reducing in Transmission Loss (1) transmission loss Transmission loss refers to loss that occurs mainly when power is transmitted from a power plant to a demand site. Current flows through a small electric resistance in the conductor of the transmission line, resulting in thermal energy which is released to the atmosphere and consumed. The Basic equation is shown in Figure 7-1.
Figure 7-1 The Basic equation
In general, hydropower stations and thermal power plants in bay area are located geographically far from the places where electricity is consumed. To reduce this transmission loss as much as possible, the electric power system is formed so that it can be delivered to a point of consumption with a higher voltage (passing current is reduced).
(2) Increase in transmission loss due to transmission line stoppage This is for backing up so that power outage does not occur in the demand area when stopping one transmission line due to inspection. Also, t is for a backup to make it possible to continue transmission on the remaining lines when equipment has a malfunction. The basic formula of transmission loss when transmitting two lines at the normal time in parallel is shown in Figure 7-2.
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Figure 7-2 The basic equation of transmission loss (transmitting two lines at the normal time in parallel)
Transmission lines may be stopped for several days, once every several years, for the maintenance and management of equipment. During this stoppage period, in the case where power is normally transmitted through two lines, power transmission is performed by one line. The transmission loss at this time is basically calculated by the formula of Figure 7-3. In that case the transmission loss will be increased four times compared to normal transmission.
Figure 7-3 Basically calculated by the equation(1 lines is outage)
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(3) Reduction of transmission loss by automating NLDC operation For this reason, it is desirable that the transmission line shutdown period is as short as possible. The procedure for stopping the transmission line is shown in Figure 7-4.
Figure 7-4 The procedure for outage the transmission
If the time of Outage Operation and Restoration Operation is shortened, there is a possibility that total stoppage time can be shortened. The following are assumed solutions that shorten downtime.
1. Shorten the time required for operation itself. 2. Move the transmission date forward by shortening the operation time.
Solution 1 is to automate the operation (operation execution, related party contact, equipment state confirmation, etc.) by the SCADA application and shorten the operation time. Solution 2 is to shorten the stop period by advancing the power transmission operation by improving the number of operations and the time period per day as a result of performing solution 1. This solution 1 and 2 is to implement the application for automation in SCADA, and they can be realized by the solutions described in 6.1.2.
(4) Estimation of transmission loss reduction Figure 7-5 is an example of a general 500 kV transmission line specification. This is the assumption of a 500 kV transmission line in Vietnam.
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Figure 7-5 Example of a general 500 kV transmission line specification
The transmission loss in each case of the two-line operation and the one-line operation (one line) in the form of the above-mentioned power transmission line is as follows.
1 line operation = 51 MW 2 line operation = 13 MW
The transmission loss reduction amount when the transmission line stoppage time is shortened by 1 day (24 hours) by the automation of the above-mentioned operation is as follows.
(51[MW]-13[MW]) × 24[h] = 912[MWh]
7.1.2 Reduction of Limitation for High-efficiency Thermal Power Plant When a power transmission line connected to a high-efficiency thermal power plant is planned outage, power plant may be output limitation. At that time, Other power plants are raised output as a response to that limitation. If the raised power plant is an inefficient fuel, there is an economic disadvantage and leads to an increase in CO2 emissions.
7.1.3 Reduction of Power Outage Recovery Time In the event of an outage due to a facility failure, the fault location is should be specified based on the information on the system and equipment status pointed to by SCADA, the recovery plan is determined, and the recovery operation is performed. However, since a large number of facility information is transmitted at the time of a power failure, the Load Dispatching Center must properly arrange these pieces of information to grasp the current state of the power system and issue instructions for restoration. Even under circumstances where the information is complicated, it is necessary to always respond in a calm and reassuring manner and judge the exact condition and handle it appropriately so as not to mis-operate. This FS report proposes to reduce the burden on operators by automating or semi - automating
7-4 application of series of restoring operations such as preparation of procedures and execution of operations. Automation allows operators to concentrate on important tasks such as grasping recovery situations, so it is possible to shorten the total time of power outage time and reduce the recovery time. That leads to improvement of power quality.
7.2 Estimation of CO2 Emissions Reduction Amount
CO2 emissions can be reduced by shortening the planned outage period of time when a planned outage of single transmission line out of two 500kV transmission lines installed in parallel. CO2 emissions are calculated based on the transmission loss reduction amount calculated previously. Also, CO2 emission coefficient α was 0.66 kg CO2 / kWh of oil fired power. The result is as follows.
3[kWh] -3[ ] 912 × 10 × 0.66 ×10 α = 602 [tCO2]
Since the 500 kV power transmission line is operating about 7000 km (2016 PDP 7) throughout Vietnam, assuming that planned outage occurs every five years. It is assumed that 1,400 km of power transmission lines are stopped annually, yearly. The amount of CO2 emission suppression is roughly as follows.
602 × 1400/400 = 2107 [tCO2]
7.3 Expected Benefits for Japan Since the demand for electricity in Vietnam is expected to increase due to economic growth in the future, the development of power supply and electric power system will continue for the time being. However, these developments are not responses to power shortages, but to deal with future demand increases. Therefore, it is assumed that the management task of EVN is changing from quantitative goal to qualitative target. Regarding qualitative response, it is a field of specialty of Japanese electric utilities and vendors that achieve world best supply quality. There is a possibility of securing the advantage from other countries' entrants. Supporting future activities at EVN together with the public and private sectors without missing this turning point leads to the creation of business opportunities for Japanese companies.
7.4 Assessing Japanese Companies’ Competitive Advantages High power quality in Japan is supported by (1) the high level of power system operation technology and (2) SCADA's design technology realizing it. In other words, it is not vendor-driven development. If Japan provide EVN with technical assistance with the public and private sectors, it will be able to get them to fully recognize the competitive advantage of Japanese power system operation technology and the importance of cybersecurity measures. Also, if NLDC reflects input from Japan in its SCADA procurement requirements and specifications, Japan can favorably promote Japanese market-oriented SCADA developed to satisfy the needs of partner countries, vs. overseas vendors that insist on product-oriented SCADA procurement.
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7.5 Possible Utilization of Financing and Government Support In Vietnam, many projects have already been developed with ODA funds, and it will be difficult to acquire funds for SCADA procurement in the future. Therefore, while seeking the possibility of procuring ODA funds, it is necessary to propose them to raise fund on their own by showing the investment effect of SCADA procurement.
7.6 Promoting this Approach to Other Countries It was confirmed that our proposals for this project is applicable to NLDC both technically and in terms of business operations. However, in terms of the structure of the company, it is necessary to appeal to the EVN headquarters. With respect to the possibility of promoting this approach to other developing countries, another round of surveys for each country will be required, because the type of electric power system, scale, supervisory control system, electric power facilities, etc. vary depending on the country, and because the best supervisory control system and SCADA also vary depending on each country.
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