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
i
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
ii
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
iii
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
1-1
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
1-2
(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)
1-3
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
2-1
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.
(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.
6.1
5
4.4
6
3.0
1
2.4
6
4.3
7
3.3
3
2.7
9
2.9
7
7.0
3
9.0
2
9.4
4
9.6
4
8.1
6
9.6
7
11.0
9
10.2
2
5.5
3
6.2
2
6.5
8
5.5
1
5.6
2
5.8
6.2
5
6.6
9
5.57
6.46 6.526.01 6.06
6.557.11 7.28
0
2
4
6
8
10
12
2009-10 2010-11 2011-12 2012-13 2013-14 2014-15 2015-16 2016-17
[%]
Agriculture Industry Service GDP
2-2
(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.
(Source: Finance Division, Ministry of Finance, Bangladesh Economic Review 2017)
Figure 2-3 Trend of Structural Transformation of Sectoral Shares in GDP
11%
3%
2%
18%
1%
8%
13%1%
10%
4%
8%
4%
3%
2%
12%
Agriculture and Forestry
Fishing
Mining and Quarrying
Manufacturing
Electricity, Gas and Water Supply
Construction
Wholesale and Retail Trade
Hotel and Restaurants
Transport, Storage & Communication
Financial Intermediations
Real Estate, Renting and Business Activities
Public Administration and Defence
Education
Health and Social Works
Community, Social and Personal Services
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
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
2-3
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
2-4
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.
2-5
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
2-6
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.
2-7
Table 2-1 Summary of Grid Code
SUBJECT Details
TRANSMISSION
SYSTEM PLANNING This identifies the method for data submissions by Users to the
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
CONDITIONS Connection Conditions specify the technical, design and
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
DESPATCH This specifies the procedure to be adopted for the scheduling
and dispatch of Generating Units to meet system demand.
FREQUENCY AND
VOLTAGE
MANAGEMENT
This describes the method by which all Users of the
Transmission System shall cooperate with the Licensee in
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
PLANNING This describes the recovery process to be followed by the
Licensee and all Users in the event of Transmission System
total or partial blackouts.
CROSS BOUNDARY
SAFETY This sets down the requirements for maintaining safe working
practices associated with cross boundary operations.
2-8
OPERATIONAL
EVENT/ACCIDENT
REPORTING
This describes the requirements for reporting, in writing,
incidents that were initially reported orally by/to other Users.
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,
COMMUNICATION
ANDDATA
ACQUISITION
This specifies the minimum operational and commercial
metering, communication and data acquisition requirements to
be provided by each User at the inter-connection points and
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
STANDARDS FOR
TRANSMISSION
(a) To ensure the quality of electric power in the Grid;
(b) To ensure that the Grid will be operated in a safe and
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)
2-9
Table 2-2 Definitions
Defined Term Definition
Connection
Conditions The technical conditions to be complied with by any User having
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)
3-1
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
3-2
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
3-3
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
3-4
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
3-5
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
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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
3-6
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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
34 Kamalaghat Munshigonj
(Banco Energy 54 MW) 54 54
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
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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
3-7
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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/)
3-8
Table 3-14 Existing Power Stations in Comilla area
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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
3-9
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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
NO. NAME INSTALLED
CAPACITY [MVA]
DERATED
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/)
3-10
3.2 Ongoing, Planned Substations
PGCB has specific plans for substations to be constructed till 2023 as shown in Figure 3-1.
(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.
(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
0
100
200
300
2018 2019 2020 2021 2022 2023
Nu
mb
er
Year
400/230 kV
400/132 kV
230/132 kV
230/33 kV
132/33 kV
0
100
200
300
400
500
2018 2023 2028 2033 2038
Nu
mb
er
Year
765/400kV
400/230kV
400/132kV
230/132kV
132/33kV
3-11
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.
(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.
0
100
200
300
400
500
600
2018 2023 2028 2033 2038
Nu
mb
er
Year
PGCB Plan
Revisiting PSMP2016
3-12
(Source: The Study Team)
Figure 3-4 The case where the number of substations and power stations increased by 20%
0
50
100
150
200
250
300
2018 2023 2028 2033 2038
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er
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BulkDhakaChittagongKhulnaRajshahiComillaMymensinghSylhetBarisal
4-1
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.
4-2
(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.
4-3
(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
4-4
(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
4-5
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/
400KV
765/
400KV
400/
230KV
400/
132KV
230/
132KV
230/
33KV
132/
33KV
TRANSMISSION
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
FACTOR 4 2 3 2 2 2 2 -
CURRENT 4 2 3 2 2 2 2 1
TAP 4 2 3 2 2 2 2 -
WINDING
TEMP 4 2 3 2 2 2 2 -
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
4-6
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)
4-7
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)
4-8
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
4-9
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)
4-10
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)
4-11
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
4-12
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)
4-13
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
4-14
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.
4-15
(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.
4-16
(Source: PGCB Web site https://www.pgcb.org.bd/PGCB/)
Figure 4-6 PGCB Optical Fiber Network
5-1
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.
5-2
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.
(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
0
4000
8000
12000
16000
20000
24000
2018 2023 2028 2033 2038
Total Substation Transmission line
5-3
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.
5-4
(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.
6-1
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.
6-2
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
6-3
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.
6-4
(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
6-5
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.
6-6
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
6-7
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.
7-1
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.
(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
0
500
1000
1500
2000
2500
3000
3500
4000
4500
2018 2023 2028 2033 2038
Pers
on
nel
Year
Operator (In current plan)
Operator (In tentative plan from 2024)
Operator (In tentative plan from 2021)
7-2
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.
(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
0
500
1000
1500
2000
2500
3000
Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb. Mar. Apr. May Jun.
[MW
h]
T E/O S/O
7-3
(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.
0
2
4
6
8
10
12
14
0
1
2
3
4
5
Jul. Aug. Sep. Oct. Nov. Dec. Jan. Feb. Mar. Apr. May. Jun.
Cu
mu
lati
ve l
oss
[m
illi
on
$]
Mo
nth
ly L
oss
[m
illi
on
$]
T E/O S/O Cumulative
7-4
(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.
2.72% 2.70%2.92% 2.82% 2.77% 2.86%
2.67%
0%
1%
2%
3%
4%
5%
2011 2012 2013 2014 2015 2016 2017
7-5
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.
Vietnam
i
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
ii
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
iii
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
iv
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
1-1
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.
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.
References:JETRO Report
https://www.jetro.go.jp/ext_images/world/asia/vn/data/vn_overview201811.pdf
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Figure 2-2 Sectoral Share of GDP at Constant Prices (2017)
Figure 2-3 Trend of Structural Transformation of Sectoral Shares in GDP
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
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
2-3
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
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
2-4
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.
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
Figure 2-5 Power Business Structure of Vietnam
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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
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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.
2-24
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
2-25
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
3-1
3 Current Situation and Prospects for Power Supply
3.1 Power Supply Structure
EVN’s organization is structured as shown in Figure 3-1.
Figure 3-1 Organization Chart
References : EVN annual report 2017
3-2
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
3-3
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)
3-4
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.
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
References:Ministry of Industry and Trade General Directorate of Energy
Viet Nam’s Power Development Plan
3-5
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.
Figure 3-3 Transmission Network Investment Plan
References:Ministry of Industry and Trade General Directorate of Energy
Viet Nam’s Power Development Plan
4-1
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)
4-2
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
Dispatching
Center
1. Control of frequency of national power system
2. Control of voltage on 500 kV
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
Regional Load
Dispatching
Center
1. Complies with the direction of the national dispatching Level
2. Control of voltage
3. Control of frequency in case of separation
4. Control of capacity of generating units
5. -Switching and handling of breakdowns
South
Regional Load
Dispatching
Center
4-3
Central
Regional Load
Dispatching
Center
6. Black start and restoration
7. Coordination with the relevant regional dispatching level upon switching
and handling of breakdown of inter-region transmission lines
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
4-4
Provincial
Load
Dispatching
Center
1. Complies with the direction of regional dispatching level
2. Control of voltage
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.
4-5
Figure 4-3 Assigned roles by voltage class
Figure 4-4 Assigned area of each Load Dispatch Center
4-6
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.
4-7
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
4-8
(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.
4-9
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.
4-10
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.
A0
A3
A1
A2RTU
RTU
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
5-9
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.
5-10
(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.
5-11
* 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
0.30
1.00
1.93
3.30
5.15
6.67
0.00
1.00
2.00
3.00
4.00
5.00
6.00
7.00
8.00
0
100000
200000
300000
400000
500000
600000
2010 2015 2020 2025 2030 2035
Estimation of Planned Outages
Total Capacity Deploy Outage Index
5-12
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.
6-1
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.
6-2
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
system
2. Control of capacity of generating units of
large power plant
3. Black start and restoration of 500 kV
4. manage of breakdown of large power
plant
5. reservoir of hydroelectric sources
6. Management of operation of EMS
function
7. Aggregation of actual operation and
report
1. Control of voltage on 500 kV
2. Switching and handling of breakdowns of 500
kV
3. Control of load of national power system
4. Sets up the basic operation mode
5. 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)
6. Analysis and identification of cause of
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.
7-1
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.
7-2
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)
7-3
(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.
7-4
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
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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.
912 × 103[kWh] × 0.66 ×10-3[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.