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MINISTRY
OF INDUSTRY AND TRADE
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SOCIALIST
REPUBLIC OF VIETNAM
Independence - Freedom - Happiness
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No.
30/2019/TT-BCT
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Hanoi,
November 18, 2019
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CIRCULAR
AMENDMENTS AND SUPPLEMENTS TO SEVERAL ARTICLES OF CIRCULAR
NO. 25/2016/TT-BCT DATED NOVEMBER 30, 2016 OF MINISTER OF INDUSTRY AND TRADE ON
ELECTRICITY TRANSMISSION SYSTEM AND CIRCULAR NO. 39/2015/TT-BCT DATED NOVEMBER
18, 2015 OF MINISTER OF INDUSTRY AND TRADE ON ELECTRICITY DISTRIBUTION SYSTEM
Pursuant to the Law on
Electricity dated December 3, 2004 and the Law on Amendment to certain Articles
of the Law on Electricity dated November 20, 2012;
Pursuant to the Government's
Decree No. 98/2017/ND-CP dated August 18, 2017, defining the functions, tasks,
powers and organizational structure of the Ministry of Industry and Trade;
Pursuant to the Government’s
Decree No. 137/2013/ND-CP dated October 21, 2013 elaborating on the
implementation of certain articles of the Law on Electricity and the Law on
Amendments to certain Articles of the Law on Electricity;
Upon the request of the
Director of the Electricity Regulatory Authority,
The Minister of Industry and
Trade hereby promulgates the Circular on amendments and supplements to several
Articles of Circular No. 25/2016/TT-BCT dated November 30, 2016 of Minister of
Industry and Trade on electricity transmission system and Circular No.
39/2015/TT-BCT dated November 18, 2015 of Minister of Industry and Trade on
electricity distribution system.
Article
1. Amendments and supplements to several Articles of the Circular No.
25/2016/TT-BCT dated November 30, 2016 of the Minister of Industry and Trade on
electricity transmission system
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“5a. Power plant’s rated
capacity refers to total rated capacity of machine sets within a power
plant which is determined when these machine sets are running at the steady and
normal operation mode, and is announced by the manufacturer of these machine
sets based on their design. The rated capacity of a solar power plant refers to
the maximum generatable output of alternating current of the plant which is calculated,
announced and commensurate with the direct current output of the solar power
plant according to a planning scheme.
6a. DIM (Dispatch
Instruction Management) refers to an information system for management of dispatch
instructions between a dispatch unit having controlling authority and a power
plant or the control center of power plants.”
2. Clause 10, 35, 49 and 53
of Article 3 shall be amended as follows:
“10. Frequency control
in a power system (hereinafter referred to as frequency control) refers to
the process of controlling a power system to maintain its stable operation,
including primary, secondary and tertiary frequency control:
a) Primary frequency control
refers to the process of instantly controlling electricity system frequency by
a large number of generator sets equipped with a governor;
b) Secondary frequency
control refers the control process following the primary frequency
control carried out through the impact of AGC system in order to bring
frequency back to the permanent permissible range of operation.
c) Tertiary frequency
control refers to the control process following the secondary control carried
out by using dispatch instructions to restore system frequency according to
regulations currently in force and ensure economic distribution of generating
capacity of generator sets.
35. Short-term flicker
perceptibility (Pst) and long-term flicker perceptibility (Plt)
refers to value measured according to applicable national standards. If
measurement values of Pst and Plt have not yet been
prescribed in national standards, they shall be valued according to IEC
standard currently in force which is announced by International
Electrotechnical Commission.
49. Power system
stabilizer (PSS) refers to a device added to the automatic voltage
regulator (AVR) to damp power output fluctuation in the electricity system.
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3. Article 7 shall be
amended as follows:
“Article 7. Phase balance
1. In the normal operation
mode, a negative sequence voltage component is not allowed to exceed 3% of
nominal voltage with respect to specific nominal voltage grades on a transmission
grid.
2. It shall be permissible
that a negative sequence voltage component may exceed the value prescribed in
clause 1 of this Article in certain points of time, but must ensure that the
value measured for at least 1 week and at the sampling rate of 10 minutes does
not exceed the prescribed limit.".
4. Clause 1 and 2 of Article
8 shall be amended and clause 6 shall be added to Article 8 as follows:
1. Voltage harmonics
a) Total harmonic distortion
is a ratio of the root-sum-square value of the voltage harmonic to the
root-mean-square value of the fundamental voltage, which is calculated
according to the following formula:
Where:
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-Vi: Root-sum-square
value of the voltage harmonic at level i and N is the highest level of the
voltage harmonic in question;
-Vl: Root-mean-square
value of the fundamental voltage (50 Hz frequency).
b) Permissible maximum value
of total harmonic distortion caused by high-level harmonic components to the
voltage level 220 kV and 500 kV is less than or equal to 3%.
2. Current harmonics
a) Total demand distortion
is a ratio of the root-sum-square value of the current harmonic to the
root-mean-square value of the fundamental current in the load and maximum
generating capacity mode, which is calculated according to the following
formula:
Where:
- TDD: Total current demand
distortion;
- Ii:
Root-sum-square value of the current harmonic at level i and N is the highest
level of the current harmonic in question;
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b) Permissible maximum value
of total demand distortion caused by high-level harmonic components to the voltage
level 220 kV and 500 kV is less than or equal to 3%.
6. It shall be accepted that
the unusual peak of harmonic on a transmission grid exceeds total harmonic
distortions specified in clause 1 and 2 of this Article, but it shall be
obligatory that 95% of value of voltage and current harmonic measured during at
least 01 week and at the sampling rate of 10 minutes is not allowed to exceed
the prescribed limit”.
5. Article 12 shall be
amended as follows:
“Article 12. Short-circuit
currents and fault clearing time
1. Permissible maximum value
of short-circuit current
a) Permissible maximum values
of short-circuit current and fault clearing time by main protection on the
electrical power transmission system are stipulated in Table 6 below:
Table
6
Permissible maximum value of short-circuit current and fault
clearing time by main protection
Voltage
level
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Maximum fault clearing time by main protection
(ms)
500
kV
50
80
220
kV
50
100
b) Main protection for an electrical
device is a major security measure, is installed and configured in order to
make first response, meet criteria concerning selectivity, reliability of a
response and response time in case of breakdown falling within the scope of
protection for such electrical device;
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2. Switchgears on a
electricity transmission grid must be able to
de-energize maximum short-circuit current running through them for at least the
next 10 years from the proposed date on which an electrical device is brought
into operation and withstand this short-circuit current for at least 01 second.
3. With respect to
hydropower and thermopower generator sets having capacity of greater than 30
MW, Total value of unsaturated sub transient
reactance of a generating set (Xd’’-%) and short-circuit reactance of a terminal transformer (Uk-%) according to the per-unit system pu (converted
into rated apparent power of a generator set) are not allowed to be less
than 40%.
If the aforesaid
requirements cannot be met, the investor shall be responsible for installing
further power reactance so that total value of Xd’’, Uk and electrical
reactance according to the per-unit system pu (converted into rated apparent
power of a generator set) is not less than 40%.
4. If value of short-circuit
current at connection point of any electrical works to an electricity
transmission system is greater than permissible maximum short-circuit as
stipulated in Table 6, owners of electrical projects shall take measures to
restrict the short-circuit current at connection points to a level lower or
equal to permissible maximum short-circuit current as stipulated in Table 6.
5. The transmission network
operator shall be responsible for informing the customer using transmission
grid about maximum value of short-circuit current at connection point for
coordination during the investment and installation of equipment, ensuring that
the switchgears are able to de-energize maximum short-circuit current at
connection point for at least the next 10 years from the proposed date on which
electrical equipment is brought into operation.”.
6. Clause 3 of Article 28
shall be amended as follows:
“3. The transmission
network operator shall be responsible for making notification to the
electricity customer of any connection proposed by such customer which is in
opposition to the approved electricity development planning in order to make
any amendment and supplement to such planning.”.
7. Clause 1 of Article 31
shall be amended as follows:
“1. The customer using
transmission grid shall be responsible for investing, installing and managing operation
of the information system under their delegated authority, and ensuring it is
connected to the information system under the control of the transmission
network operator and the dispatch level having controlling rights; ensuring
that data (including data of SCADA, PMU and fault recorder) are communicated
and transmitted in a full, reliable and continuous manner for the purposes of
operation of electrical power system and markets. Means of communications
serving dispatching and operation activities in an electricity transmission
system, including direct communication channel, telephone, facsimile and DIM,
must operate in a reliable and continuous manner.”.
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“1. Transformers from 220
kV and on, power plants with installed capacity greater than 30 MW and power
plants connected to the transmission grid which is not yet connected to the
Control Center must be equipped with a Gateway or RTU, and must be set up with
two connections physically independent of the SCADA system of the dispatch
level vested with controlling rights.
2. Transformers from 220 kV
and on, power plants with installed capacity greater than 30 MW and power
plants connected to the transmission grid which is connected to, controlled and
manipulated remotely by the Control Center must be equipped with a Gateway or
RTU, and must be set up with an connection to the SCADA system of the dispatch
level vested with controlling rights and two connections to the control system
at the Control Center.
9. Article 36 shall be
amended as follows:
“Article 36. Automatic load
shedding system
1. The customer using
transmission grid shall be responsible for cooperating with relevant units in
unifying the installation of the automatic frequency load shedding system and
ensuring that it operates in accordance with calculations and requirements of
the dispatch level vested with controlling rights.
2. The system must be
designed and configured to meet following requirements:
a) Reliability not less than
99%;
b) Any unsuccessful load
shedding must not affect operation of the entire electricity system;
c) Load shedding procedures
and amount of shed power must be in compliance with level of distribution by the
dispatch level vested with controlling rights, and must not be changed in any
case without consent from the dispatch level vested with controlling rights.
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10. Clause 2 of Article 37
shall be amended as follows:
“2. Requirements for
connection from the Control Center
a) Requirements for
connection to communications system
- There is a data
transmission line to be connected to the information system of the dispatch
level vested with controlling rights. If multiple dispatching levels with
control authority exist, an information sharing method must be agreed by all
the dispatching levels;
- There are two data
transmission lines (working and standby) to be connected to the control and
information system of power plants or stations remotely controlled by the
Control Center;
- Means of communications
serving dispatching activities, inter alia, including direct communication
channel, telephone, facsimile, DIM and computer network, must be in good
working condition.
b) Requirements for
connection to SCADA system
- There is a connection to
the SCADA of the dispatch level vested with controlling rights. If multiple
dispatching levels with control authority exist, all the dispatching levels
shall be responsible for sharing information;
- There are two connections
to RTU/Gateway, control system of power plants, electricity stations and
switchgears on the electrical grid remotely controlled by the Control Center;
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11. Clause 3 of Article 38
shall be amended as follows:
“3. The generating set must
be capable of adjusting primary frequency which falls outside of the dead band
of the governor, meeting all of its demands for capacity for controlling
primary frequency within 15 seconds and maintaining such capacity for at least
15 seconds. Primary frequency controlling capacity of a generating set may vary
depending on actual frequency deviations and set parameters requested by
electricity system and market operator.”.
12. Article 42 shall be
amended as follows:
“Article 42. Technical requirements of wind and solar power plants
1. Wind and solar power
plants must be capable of maintaining generation of active power in the
following modes:
a) Free generation mode: Generating
possible highest power, depending on transformation of primary energy source
(wind or solar energy);
b) Generating capacity control mode:
Wind and solar power plants
must be capable of restricting electric output according to dispatch
instructions in the following cases:
- If primary energy source
deviates to the degree lower than the value limited according to dispatch
instructions, possible highest power must be generated;
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2. Wind and solar power plants
which are, at any time, connected to transmission grids must be capable of
maintaining generation of power for a minimum period of time in proportion to power-generating
frequency band prescribed in Table 8 below:
Table
8
Required minimum timelength for maintenance of power
generation at wind and solar power generation plants in proportion to frequency
bands of electricity systems
Frequency
band
Required
minimum timelength
From
47.5 Hz to 48.0 Hz
10
minutes
Greater
than 48 Hz to less than 49 Hz
30
minutes
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Continuous
generation
Greater
than 51 Hz to 51.5 Hz
30
minutes
Greater
than 51.5 Hz to 52 Hz
01
minute
3. When the electricity
system’s frequency is greater than 50.5 Hz, wind and solar power plants may
reduce active power on the comparative slope of droop characteristics within
the steep gradient range of between 2% and 10%. Set value of the slope of droop
characteristics is calculated and determined by the dispatch level vested with
controlling rights.
4. Wind and solar power
plants must be capable of adjusting reactive power according to characteristics
shown in the following diagram and described in point a and b of this clause:
a) If a power plant
generates an active power greater or equal to 20% of rated active power and
voltage at a connection point in the nominal voltage band of ± 10%, such power
plant must be capable of adjusting reactive power continuously in the power
factor range from 0.95 (corresponding to reactive power generation mode) to
0.95 (corresponding to reactive power receiving mode) at the connection point
in proportion to rated power;
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5. Voltage control mode and
reactive power:
a) Wind and solar power
generation plants must be capable of controlling voltage and reactive power in
the following modes:
- Mode of controlling
voltage according to voltage-adjusting droop characteristics (characteristics
of the relation between voltage and reactive power);
- Mode of control according
to the set value of reactive power;
- Mode of control according
to power factors
b) If voltage at connection
point is within the band of ± 10 % of rated voltage, a wind or solar power
plant must be capable of adjusting voltage at the low-voltage side of the
step-up transformer with deviation no more than ± 0.5 % of rated voltage
(compared to set voltage value) whenever reactive power of the generating set
is within the permissible working band for no longer than 05 seconds.
6. Wind and solar power
plants which are, at any time, connected to transmission grids must be capable
of maintaining generation of power commensurate with the voltage band at the
connection point within the following specific time points:
a) If voltage is less than
0.3 pu, minimum maintenance time will be 0.15 seconds;
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Tmin
= 4 x U – 0.6
Where:
- Tmin (second):
Minimum time required to maintain power generation;
- U (pu): Actual voltage at connection point calculated by pu
(relative value).
c) If voltage ranges from 0.9 pu to under 1.1 pu, wind and solar
power plants must maintain continuous generation;
d) If voltage ranges from
1.1 pu to under 1.15 pu, wind and solar power plants must maintain power
generation for 3 seconds;
dd) If voltage ranges from
1.15 pu to under 1.2 pu, wind and solar power plants must maintain power
generation for 0.5 seconds.
7. The level of phase
unbalance, total harmonic distortion and flicker perceptivity caused by wind or
solar power plants at connection points shall not be allowed to exceed values
specified in Article 7, 8 and 9 herein.
8. Wind or solar power
plants must invest in control and automatic equipment and systems to ensure
stable, reliable and confidential connection to Automatic Generation Control
(AGC) of the electricity system and market operator serving remote control of their power generation capacity
according to the dispatch instruction received from the electricity system and
market operator”.
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“a) Secondary frequency regulation reserve and quick-start reserve levels
are lower than required in normal operation mode”.
14. Point b of clause 3 of
Article 64 shall be amended as follows:
“b) Carry out load shedding on each line through an automatic
shedding relay or under dispatch instruction.”
15. Clause 2a shall be
inserted after clause 2 of Article 69 as follows:
“2a. Provide information
about primary energy source (hydrographical information necessary for
hydropower plants, information about coal – oil – combustible substances
necessary for thermopower plants, meteorological monitoring information
necessary for wind or solar power plants), forecast power generation plant’s capacity
and output, and transmitting data to the electricity system and market
operator.”
16. Article 72 shall be
amended as follows:
“Article 72. Ancillary
services
Ancillary services in the
electricity system shall comprise:
1. Secondary frequency
control (Secondary frequency regulation).
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3. Voltage adjustment.
4. Must-run operation reserves used for electricity system
security purposes.
5. Black start.”
17. Article 73 shall be
amended as follows:
“Article 73. Technical
requirements of ancillary services
1. Secondary frequency
regulation: The generating sets providing secondary frequency regulation services
must be capable of starting to provide frequency regulation capacity within 20
seconds of receipt of AGC signals from the electricity, providing registered
secondary frequency regulation capacity within 10 minutes, and maintaining this
capacity level within at least 15 minutes.
2. Quick start. Generating sets providing quick-start reserve must be capable
of increasing to the rated power within 25 minutes and maintaining it for a
minimum of 08 hours.
3. Voltage adjustment: Generating sets providing voltage adjustment service must be
capable of changing reactive power outside the adjustment band prescribed in
Clause 2, Article 38 herein, meeting requirements of the electricity system and
market operator.
4. Must-run operation reserves
used for electricity system security purposes: Generating
sets providing must-run operation for electricity system security purposes must
be capable of increasing to a rated power within one hour and maintaining such
rated power for a minimum of eight hours (excluding the time of starting).
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18. Article 74 shall be
amended as follows:
“Article 74. Determination
of demands and provision of ancillary services
1. General principles for
determining demands for ancillary services, including:
a) Maintain electrical power and capacity reserve levels of the
electricity system in order to meet power system operation and security
standards;
b) Ensure minimum expenses in accordance with conditions and
obligations of the national electricity system.
2. Power system and market
operator shall be responsible for calculating and reporting to the Vietnam
Electricity Corporation on demands for ancillary services for the national
electricity system according to Procedures for determination of demands and
provision of ancillary services, which are issued by the Electricity Regulatory
Authority.
3. Before November 1 each
year, the Vietnam Electricity Corporation shall be responsible for petitioning
the Electricity Regulatory Authority to approve ancillary service demands of
the national electricity system in the next year as a basis for formulation of
plans to purchase and call for ancillary services in the next year’s plan for
operation of the national electricity system.”
19. Point b of clause 1 of
Article 85 shall be amended as follows:
“b) In case of the
unbalancing state of the power system, the electricity system and market
operator must have recourse to other generating sets to provide ancillary
services and adjust the existing power output, based on the mobilization
sequence of generating sets in the power system, in order to restore the power
system to the balanced state and maintain the prescribed reserve level.”
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“4. The electricity
transmission system operator shall be responsible for submitting written
reports under clause 1, 2 and 3 of this Article by post and electronic
mail.".
21. Clause 5 shall be added
to Article 91 as follows:
“5. The power system and
market operator shall be responsible for submitting written reports prescribed
in clause 1, 2, 3 and 4 of this Article by post and electronic mail.".
Article
2. Amendments and supplements to several Articles of the Circular No. 39/2015/TT-BCT
dated November 18, 2015 of the Minister of Industry and Trade on electricity distribution
system
1. Clause 3a shall be
inserted after clause 3 of Article 3 as follows:
“3a. Power plant’s rated
capacity refers to total rated capacity of machine sets within a power plant
which is determined when these machine sets are running at the steady and
normal operation mode, and is announced by the manufacturer of these machine
sets based on their design. The rated capacity of a solar power plant refers to
the maximum generatable alternating current power of the plant which is
calculated, announced and commensurate with the direct current power of the
solar power plant according to a planning scheme.”.
2. Article 5 shall be
amended and supplemented as follows:
“Article 5. Voltage
1. Nominal voltage levels in
a power distribution system comprise 110 kV, 35 kV, 22 kV, 15 kV, 10 kV, 06 kV
and 0.38 kV.
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a) The permissible operating
voltage deviation at busbar installed on the power distribution grid of a power
distributor compared to the nominal voltage ranges between + 10% and - 05%;
b) The permissible operating
voltage deviation at a connection point compared to the nominal voltage shall
be as follows:
- Such deviation at a
connection point to a customer is ± 05%;
- Such deviation at a
connection point to a factory is between + 10% and - 05%;
- If a power plant and
customer are connected to the same busbar or the same line in the power
distribution grid, voltage at a connection point shall be decided by the power
distributor operating the regional power grid, ensuring conformance to
technical requirements of operation of power distribution systems and voltage
quality for customers in accordance with regulations in force.
3. If a power grid is in the
normal state after facing failure, it shall be permissible that the deviation
of voltage at a connection point to a customer who is directly affected by such
failure falls within the range from + 5% to - 10% in comparison to the nominal
voltage.
4. In the failure or
recovery mode, it shall be permissible that the deviation of voltage in a power
distribution grid falls within the ± 10% range compared to the nominal voltage.
5. During the failure time,
voltage at the happening site and adjacent areas is likely to decrease
transiently to the zero value at the affected phase or increase by 110% of the
nominal voltage at the unaffected phases until such failure is ruled out.
6. Voltage fluctuation
occurring at a connection point in an electricity distribution grid which is
caused by a fluctuation arising from a load of a user or manipulation of a
switchgear inside a power plant shall not exceed 2.5% of the nominal voltage
and fall within the permissible operating voltage range prescribed in clause 2
of this Article.
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3. Article 6 shall be
amended as follows:
“Article 6. Phase balance
1. In normal operation mode,
negative sequence voltage components are not allowed to exceed 03% of the nominal
voltage with respect to the voltage level of 110 kV, or 05% of the nominal
voltage with respect to the medium and low voltage level.
2. It shall be permissible
that a negative sequence voltage component may, at any point of time, exceed
the value prescribed in clause 1 of this Article, but must ensure that the value
measured for at least 1 week and at the sampling rate of 10 minutes does not
exceed the prescribed limit.".
4. Article 7 shall be
amended and supplemented as follows:
“Article 7. Harmonics
1. Voltage harmonics:
a) Total harmonic distortion
is a ratio of the root-sum-square value of the voltage harmonic to the
root-mean-square value of the fundamental voltage, which is calculated
according to the following formula:
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- THD: Total voltage
harmonic distortion; Vi: Root-sum-square value of the voltage
harmonic at level i and N is the highest level of the voltage harmonic in
question;
- Vl:
Root-mean-square value of the fundamental voltage (50 Hz frequency).
b) The permissible maximum
voltage harmonic distortion in the power distribution grid prescribed in Table
1a shall be as follows:
Table
1a
Permissible
maximum voltage harmonic distortion
Voltage
level
THD
Individual
distortion
110kV
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1.5%
Medium
voltage
5%
3.0%
Low
voltage
8%
5%
2. Current harmonics:
a) Total demand distortion
is a ratio of the root-sum-square value of the current harmonic to the
root-mean-square value of the fundamental current in the load/maximum
generating capacity mode, which is calculated according to the following
formula:
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Where:
- TDD: Total current demand
distortion;
- Ii:
Root-sum-square value of the current harmonic at level i and N is the highest
level of the current harmonic in question;
- IL:
Root-mean-square value of the fundamental current (50 Hz frequency) in load and
maximum generating capacity mode (load and maximum generating capacity are
average values of 12 loads and maximum generating capacities corresponding to
preceding 12 months. In case of new connection points or failure to collect
values of load or maximum generating capacity corresponding to preceding 12
months, value of load and maximum generating capacity during the entire
duration of measurement will be used).
b) Power plants connected to
power distribution grids shall not cause current harmonic distortion to exceed
the values prescribed in Table 1b hereunder:
Table
1b
Permissible
maximum current harmonic distortion of power plants
Voltage
level
Total
distortion
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110kV
3%
2%
Medium
and low voltage
5%
4%
c) Electrical loads
connected to power distribution grids shall not cause current harmonic
distortion to exceed the values prescribed in Table 1c hereunder:
Table
1c
Permissible
maximum current harmonic distortion of electrical loads
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Total
distortion
Individual
distortion
110kV
4%
3.5%
Medium
voltage
8%
7%
Low
voltage
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20%
with respect to a load with a power of <50 kW
10%
with respect to a load with a power of ≥ 50 kW
15%
with respect to a load with a power of <50 kW
3. It shall be accepted that
the unusual peak of harmonic on a transmission grid exceeds total harmonic
distortions specified in clause 1 and 2 of this Article, but it shall be
obligatory that 95% of value of voltage and current harmonic measured during at
least 01 week and at the sampling rate of 10 minutes is not allowed to exceed
the prescribed limit.”.
5. Article 8 shall be
amended as follows:
“Article 8. Voltage flicker
perceptivity
1. In the normal operating
mode, flicker perceptivity levels at all connections shall not be allowed to
exceed the limits prescribed in Table 2 hereunder:
Table
2
Voltage
flicker perceptivity
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Permissible
flicker perceptivity
110kV
Pst95%
= 0.80
Plt95%
= 0.60
Medium
voltage
Pst95%
= 1.00
Plt95%
= 0.80
Low
voltage
Pst95%
= 1.00
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2. Short-term flicker
perceptivity (Pst) and long-term flicker perceptivity (Plt)
are values measured according to existing national standards. If measurement
values of Pst and Plt have not yet been prescribed in
national standards, they shall be valued according to IEC standard currently in
force which is announced by International Electrotechnical Commission.
6. Article 9 shall be
amended as follows:
“Article 9. Short-circuit
currents and fault clearing time
1. Permissible maximum
values of short-circuit current and fault clearing time by main protection on
electrical power distribution systems are stipulated in Table 3 below:
Table
3
Permissible
maximum value of short-circuit current and fault clearing time
Voltage
levels
Permissible
maximum short-circuit current
(kA)
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(ms)
110kV
31.5
150
Medium
voltage
25
500
2. Switchgears on a
electricity distribution grid must be able to de-energize maximum short-circuit
current running through them for at least the next 10 years from the proposed
date on which an electrical device is brought into operation and withstand this
short-circuit current for at least 01 second.
3. As for a medium-voltage
distribution line that is divided into multiple segments and is difficult to be
protected by a coordination between switchgears on a power grid, it shall be
permissible that timelength of elimination of failure by main protection at
several switching points is greater than the timelength prescribed in clause 1
but must be less than 1 second, provided that safety for equipment and power
grid must be assured.
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5. The distribution network
operator shall be responsible for informing the customer using distribution
grid about maximum value of short-circuit current at connection point for
coordination during the investment and installation of equipment, ensuring that
the switchgears are able to de-energize maximum short-circuit current at
connection point for at least the next 10 years from the proposed date on which
electrical equipment is brought into operation.”.
7. Article 17a shall be
added after Article 17 as follows:
Article 17a. Dissemination
of information about reliability of power supply, electrical energy loss and
customer service quality
1. By the 10th
day of each month, the power distribution grid operator shall be responsible
for posting on its website information about reliability of power supply,
electrical energy loss and customer service quality in the preceding month.
2. By the 31st
day of January each year, the power distribution grid operator shall be
responsible for posting on its website information about reliability of power
supply, electrical energy loss and customer service quality in the preceding
year.”.
8. Clause 2 of Article 28
shall be amended as follows:
“2. If the plan for power
connection proposed by a customer is not relevant to the approved power
development plan, the distribution network operator or the power distribution
and retailing operator shall be responsible for making notification to the
electricity customer of any amendment and supplement to the planning scheme in
accordance with regulations in force.”.
9. Article 32 shall be
amended as follows:
“Article 32. Harmonic
distortion requirements
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10. Clause 1 and 2 of
Article 38 shall be amended as follows:
“1. Power plants connected
to distribution grids with the capacity of at least 10 MW (irrespective of
connection voltage levels) and transformer substations of 110 kV not yet
connected to the Control Center must be equipped with a Gateway or RTU, and
must be set up with two connections physically independent of the SCADA system
of the dispatch level vested with controlling rights. If power plants or
transformer substations operate at multiple levels vested with controlling
rights, dispatch levels shall be responsible for sharing information necessary
for coordination in operation of the power system.
2. Power plants connected to
distribution grids with the capacity of at least 10 MW and transformer substations
of 110 kV already connected to the Control Center must be equipped with a
Gateway or RTU, and must be set up with one connection to the SCADA system of
the dispatch level vested with controlling rights, and two connections to the
control system at the Control Center.”.
11. Article 40 shall be
amended and supplemented as follows:
“Article 40. Requirements
of wind power plants, solar power plants connected to power distribution grids
at the minimum level of medium voltage
1. Wind and solar power plants
must be capable of maintaining generation of active power in the following
modes:
a) Free generation mode: Generating
possible highest power, depending on transformation of primary energy source
(wind or solar energy);
b) Generating capacity
control mode:
Wind and solar power plants
must be capable of restricting electric output according to dispatch
instructions in the following cases:
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- If primary energy source
deviates to the degree equal to or greater than the value limited according to
dispatch instructions, electrical power output equaling the value limited
according to dispatch instruction shall be produced provided that tolerance
falls within the band ± 01% of the rated capacity.
2. Wind and solar power
plants which are, at any time, connected to transmission grids must be capable
of maintaining generation of power for a minimum period of time in proportion
to power-generating frequency band prescribed in Table 8 below:
Table
8
Required
minimum timelength for maintenance of power generation at wind and solar power
generation plants in proportion to frequency bands of electricity systems
Frequency
band
Required
minimum timelength
From
47.5 Hz to 48.0 Hz
10
minutes
From
greater than 48 Hz to less than 49 Hz
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From
49 Hz to 51 Hz
Continuous
generation
From
greater than 51 Hz to 51.5 Hz
30
minutes
From
greater than 51.5 Hz to 52 Hz
01
minute
3. When the electricity
system’s frequency is greater than 50.5 Hz, wind and solar power plants may
reduce active power on the comparative slope of droop characteristics within
the steep gradient range of between 2% and 10%. Set value of the slope of droop
characteristics is calculated and determined by the dispatch level vested with
controlling rights.
4. Wind and solar power
plants must be capable of adjusting reactive power according to characteristics
shown in the following diagram and described in point a and b of this clause:
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b) If a power plant
generates an active power less than 20% of rated power, such power plant may
reduce ability to receive or generate reactive power in accordance with
characteristics of the generating set.
5. Voltage control mode and
reactive power:
a) Wind and solar power
generation plants must be capable of controlling voltage and reactive power in
the following modes:
- Mode of controlling
voltage according to voltage-adjusting droop characteristics (characteristics
of the relation between voltage and reactive power);
- Mode of control according
to the set value of reactive power;
- Mode of control according
to power factors
b) If voltage at connection
point is within the band of ± 10 % of rated voltage, a wind or solar power
plant must be capable of adjusting voltage at the low-voltage side of the
step-up transformer with deviation no more than ± 0,5 % of rated voltage
(compared to set voltage value) whenever reactive power of the generating set
is within the permissible working band for no longer than 05 seconds.
6. Wind and solar power plants
which are, at any time, connected to transmission grids must be capable of
maintaining generation of power commensurate with the voltage band at the
connection point within the following specific time points:
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b) If voltage ranges from
0.3 pu to under 0.9 pu, minimum maintenance time will be calculated according
to the following formula:
Tmin
= 4 x U – 0.6
Where:
- Tmin (second):
Minimum time required to maintain power generation;
- U (pu): Actual voltage at
connection point calculated by pu (relative value).
c) If voltage ranges from
0.9 pu to under 1.1 pu, wind and solar power plants must maintain continuous
generation;
d) If voltage ranges from
1.1 pu to under 1.15 pu, wind and solar power plants must maintain power
generation for 03 seconds;
dd) If voltage ranges from
1.15 pu to under 1.2 pu, wind and solar power plants must maintain power
generation for 0.5 seconds.
7. The level of phase
unbalance, total harmonic distortion and flicker perceptivity caused by wind or
solar power plants at connection points shall not be allowed to exceed values
specified in Article 6, 7 and 8 herein.
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12. Article 41 shall be
amended and supplemented as follows:
“Article 41. Requirements
of solar power plants connected to power distribution grids at the minimum
level of low voltage
In order to make connection
to low-voltage power grids, solar power systems must meet the following
requirements:
1. Connection capacity
a) Total installed capacity
of the solar power system connected to the low voltage level of the step-down
transformer substation shall not be allowed to exceed the installed capacity of
that transformer substation;
b) Solar power system with
the maximum capacity of less than 20 kWp may be connected to the 1-phase or
3-phase power grid according to an agreement with the power distribution grid
operator, the power distribution grid and retailing operator;
c) Solar power system with
the minimum capacity of 20 kWp must be connected to the 3-phase power grid.
2. Solar power systems which
are, at any time, connected to low-voltage power grids must be capable of
maintaining generation of power for a minimum period of time in proportion to
power-generating frequency band prescribed in Table 5a hereunder:
Table
5a
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Frequency
band
Required
minimum timelength
From
48 Hz to 49 Hz
30
minutes
From
49 Hz to 51 Hz
Continuous
generation
From
51 Hz to 51.5 Hz
30
minutes
3. If frequency is greater
than 50.5 Hz, the solar power system with the minimum capacity of 20 kWp must
reduce active power according to the following formula:
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Where:
- ∆P: Level
of reduction in active power (MW);
- Pm: Active
power consistent with that determined at the time prior to power reduction
(MW);
- fn: Frequency
of the power system prior to power reduction (Hz).
4. Solar power systems must
be capable of maintaining continuous generation of power within voltage bands
at connections as prescribed in Table 5b hereunder:
Table
5b
Minimum
time of maintenance of generation in proportion to voltage bands at connections
Voltage
at connections
Required
minimum timelength
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Not
required
From
50% to 0.85 of the nominal voltage
2
seconds
From
85% to 110% of the nominal voltage
Continuous
generation
From
110% to 120% of the nominal voltage
2
seconds
120%
greater than the nominal voltage
Not
required
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6. Solar power systems shall
not cause invasion of direct current into power distribution grids to the
extent that such current is 0.5% higher than the rated current at a connection
point.
7. Solar power systems
connected to low-voltage power grids must conform to regulations on voltage,
phase balance, harmonics, flicker perceptivity and earthing mode prescribed in
Article 5, 6, 7, 8 and 10 herein.
8. Solar power systems shall
be equipped with security devices meeting the following requirements:
a) Automatically disconnect
power distribution grids in case of failure occurring inside a solar power
system;
b) Automatically disconnect
power distribution grids in case of loss of power supplied from power
distribution grids and do not generate power on power distribution grids in case
of loss of electricity currently taking place on power distribution grids;
c) Do not automatically
reconnect power grids due to inconformity with the following requirements:
- Power grid’s frequency is
maintained within the band from 48Hz to 51Hz during the minimum period of 60
seconds;
- Voltage of all phases at
connections is maintained within the band from 85% to 110% of the nominal
voltage during the minimum period of 60 seconds
d) With respect to solar
power systems connected to 3-phase low-voltage power grids, customers demanding
connection must negotiate and agree on requirements regarding security systems
with the power distribution grid operator, inter alia including at least
protections specified in point a, b and c of this clause, over-voltage,
low-voltage and frequency protection".
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“2. Requirements for
connection from the Control Center
a) Requirements for
connection to communications systems:
- There is a data
transmission line to be connected to the information system of the dispatch
level vested with controlling rights. If multiple dispatching levels with
control authority exist, an information sharing method must be agreed by all
the dispatching levels;
- There are two data transmission
lines (working and standby) to be connected to the control and information
system of power plants or stations remotely controlled by the Control Center;
- Means of communications
serving dispatching activities, inter alia, including direct communication
channel, telephone, facsimile, DIM and computer network, must be in good
working condition.
b) Requirements for
connection to the SCADA system:
- There is a connection to
the SCADA of the dispatch level vested with controlling rights. If multiple
dispatching levels with control authority exist, all the dispatching levels
shall be responsible for sharing information;
- There are two connections
to RTU/Gateway, control system of power plants, electricity stations and
switchgears on the electrical grid remotely controlled by the Control Center.
c) The Control Center must
install a monitoring screen and make connection to closed-circuit television
cameras at power plants, electricity stations and switchgears on the electrical
grid to send information to the Control Center.
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“3. If there is a shortage
of information and documents prescribed in clause 2 of this Article at the time
of submitting application for connection to medium-voltage and 110 kV distribution
grids, customers using distribution grids shall be responsible for making an
agreement with the power distribution grid operator on provision of
information, documents and specifying such agreement in the connection
agreement.”.
15. The title of Article 44
shall be revised as follows:
“Article 44. Steps in
reaching a connection agreement with customers using power distribution grids
who apply for connection at the level of 110 kV voltage and customer owning
generating sets who apply for connection to medium-voltage power grids”
16. Point c of clause 2 of
Article 44 shall be amended as follows:
“c) Collect opinions from
the dispatch level vested with controlling rights and units related to
connection about any impact of connection on power systems, regional power
grids, requests for connection to communications systems and SCADA systems of
the dispatch levels vested with controlling rights, requirements concerning
protection relays, automatization and other matters regarding technical
requirements of devices at connection points;".
17. Clause 2 of Article 45
shall be amended as follows:
“2. Customers using power
who install their own power substations connected to medium-voltage power
grids: Within the maximum duration of 02 working days of receipt of all valid
documentation from customers, the power distribution grid operator or the power
distribution and retailing operator shall be responsible for surveying the
site, negotiating and signing connection agreements with these customers.”.
18. Clause 2 of Article 51
shall be amended as follows:
“2. Customers using power
who install their own power substations connected to medium-voltage power
grids: Within 05 working days of receipt of all application documentation for
full completion of power connection at valid points of customers using power
that install their own power stations connected to medium-voltage power grids
in accordance with Article 48 herein, the power distribution grid operator
shall be responsible for cooperating with customers in completing power
connection for trial test, carrying out commissioning and completing power
connection for official distribution of power to customers applying for
connection.".
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“2. If two parties involved
do not agree on test results and causes of any violation, they must negotiate
on the scope of inspection in order for customers to hire independent testing
bodies to carry out repeated inspection and test. If test results of independent
testing bodies indicate violations are caused due to customer's devices, and
customers refuse to remedial actions or fail to complete these actions within
the duration agreed upon with the power distribution grid operator, this
operator may disconnect customer's devices from power distribution grids. Remedial
duration shall be agreed upon by two parties. If two parties do not agree on
such duration, they may resolve dispute according to regulations on inspection
of power activities, use of power and handling of dispute arising from power
purchase agreements issued by the Ministry of Industry and Trade.”.
6. During the operation
period, if there is any risk to operational safety of the power system which is
caused by customer’s devices, the power distribution grid operator must immediately
inform the dispatch level vested with controlling rights, customers using power
distribution grids that install their own power stations in order to take
remedial actions and eliminate any risk to operational safety for the power
system. If such risk to operational safety is caused by technical errors which
are unable to be corrected or there is any suspect that customers cause adverse
impacts during use of power distribution grids, the power distribution grid
operator may request customers to carry out re-inspection or retesting of
devices within customer’s remit in accordance with clause 1 and 2 of this
Article.”.
20. Point d of clause 2 of
Article 64 shall be amended as follows:
“d) The power generating
unit shall be responsible for providing information about primary energy source
(hydrographical information necessary for hydropower plants, information about
coal – oil – combustible substances necessary for thermopower plants,
meteorological monitoring information necessary for wind or solar power
plants), forecast power generation plant’s capacity and output, and
transmitting data to the electricity system and market operator.”
21. Article 79 shall be
amended as follows:
“Article 79. Electrical
load control
1. Control of electrical
loads in a power system shall comprise the following measures:
a) Suspension and decrease
of power supply;
b) Load shedding;
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2. Dispatch levels vested
with controlling rights and the power distribution grid operator shall take
control of loads according to procedures for dispatch of the national
electricity system and Regulations on contents and procedures for implementation
of programs for load adjustment adopted by the Ministry of Industry and
Trade.”.
22. Clause 1 of Article 82
shall be amended as follows:
“1. Automatic load shedding
is an act by a frequency, voltage and power relay to selectively get rid of a
load in order to keep a power system operate within the permissible limit and
prevent any large-scale losses in electricity.”. 23. Clause 4 shall be added
to Article 99 as follows:
“4. The Electricity
Corporation of Vietnam and the electricity distribution system operator shall
be responsible for submitting written reports under clause 1, 2 and 3 of this
Article by post and electronic mail.".
Article
3. Repeal of several articles and clauses of the Circular No. 25/2016/TT-BCT
dated November 30, 2016 of the Minister of Industry and Trade on electricity
transmission system and Circular No. 39/2015/TT-BCT dated November 18, 2015 of
Minister of Industry and Trade on electricity distribution system
1. Repealing clause 8 and 9,
clause 36 of Article 3 and Chapter IV in the Circular No. 25/2016/TT-BCT dated
November 30, 2016 of the Minister of Industry and Trade on electricity
transmission system.
2. Repealing Chapter IV and
Article 101 of Circular No. 39/2015/TT-BCT dated November 18, 2015 of the
Minister of Industry and Trade on electricity distribution system.
Article
4. Entry into force
1. This Circular shall enter
into force on January 3, 2020.
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MINISTER
Tran Tuan Anh