DL/T 5149-2020 (DL/T5149-2020, DLT 5149-2020, DLT5149-2020) & related versions
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Technical code for designing computerized monitoring and control system of 220~500kV substations
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DL/T 5149-2020: PDF in English (DLT 5149-2020)
DL/T 5149-2001
POWER INDUSTRY STANDARD OF
THE PEOPLE’S REPUBLIC OF CHINA
ICS 27.100
P 62
Filing No.: J152-2002
P DL/T 5149-2001
Technical code for designing computerized
monitoring and control system of 220~500kV
substations
ISSUED ON: DECEMBER 26, 2001
IMPLEMENTED ON: MAY 1, 2002
Issued by: National Economic and Trade Commission of the People’s
Republic of China
Table of Contents
Foreword ... 5
1 Scope of application ... 7
2 Normative references ... 8
3 General ... 9
4 Main terms ... 10
5 System composition ... 12
5.1 System structure ... 12
5.2 Network structure ... 12
5.3 Hardware equipment ... 13
5.4 Software system ... 14
5.5 Technical indicator ... 15
6 System functions ... 18
6.1 Data acquisition and processing ... 18
6.2 Database establishment and maintenance ... 18
6.3 Control operation ... 19
6.4 Anti-mislocking ... 20
6.5 Synchronizing ... 20
6.6 Alarm processing ... 21
6.7 Event sequence recording and accident recall ... 21
6.8 Screen generation and display ... 22
6.9 Online calculation and tabulation ... 22
6.10 Electric energy processing ... 23
6.11 Telecontrol function ... 23
6.12 Clock synchronization ... 23
6.13 Man-machine interaction ... 24
6.14 System self-diagnosis and self-recovery ... 25
6.15 Interface with other devices ... 25
6.16 Operation management ... 26
7 Signal input/output ... 27
7.1 Analog input signal ... 27
7.2 On-off input signal... 27
7.3 Electrical energy data input signal ... 27
7.4 On-off output signal... 28
8 Equipment layout ... 29
8.1 Layout of station level equipment ... 29
8.2 Layout of bay level equipment ... 29
8.3 Screen cabinet structure and screen layout ... 29
9 Venue and environment ... 30
10 Power supply ... 31
11 Lightning protection and grounding ... 32
12 Cable selection and laying ... 34
Appendix A (Indicative) Description of the words in this Code ... 35
Appendix B (Indicative) Analog signal ... 36
Appendix C (Indicative) Main on-off input signals ... 43
Appendix D (Indicative) Electrical energy signal acquisition parameters ... 45
Appendix E (Indicative) On-off output signals ... 47
1 Scope of application
This Code is applicable to the design of computerized monitoring and control
system for the newly built 220kV hub substations and 500kV (330kV)
substations. Expansion and reconstruction projects of the same voltage
grade may be carried out with reference.
2 Normative references
The following standards include provisions that constitute provisions of this
Code by reference in this Code. At the time of publication of this Standard, the
editions indicated are valid. All standards are subject to revision. Parties to
this Standard shall explore the possibility of using the latest editions of the
following standards.
GB/T 50217-1994 Code for design of cables electric work
GB/T 17626-1998 Electromagnetic compatibility – Testing and
measurement techniques
DL/T 630-1997 Technical requirement for RTU with a.c. electrical
quantities input, discrete sampling
DL/T 634-1997 Telecontrol equipment and systems – Part 5: Transmission
protocols – Section 101 Companion standard for basic telecontrol tasks
DL/T 667-1999 Telecontrol equipment and systems – Part 5: Transmission
protocol – Section 103 Companion standard for the information interface of
protection equipment
DL/T 719-2000 Telecontrol equipment and systems – Part 5: Transmission
protocol – Section 102 Companion standard for the transmission of
integrated totals in electric power systems
DL 5002-1991 Specifications for the design of dispatching automation in
district electric power systems
DL 5003-1991 Specifications for the design of dispatching automation in
electric power systems
DL/T 5136-2001 Technical code for designing of electrical secondary
wiring in fossil fuel power plants and substations
DL/T 5137-2001 Technical code for designing electrical measuring and
energy metering device
SDJ 2-1988 Technical code for designing 220~500kV substations
3 General
3.0.1 This Code is specific design regulations for 500kV (330kV)
substations and 220kV hub substations using the computerized monitoring
and control system, and is supplementary regulations for implementing the
relevant provisions of Technical code for designing 220~500kV substations
and Technical code for designing of electrical secondary wiring in fossil fuel
power plants and substations.
3.0.2 The design of the computerized monitoring and control system of
substations shall follow the following principles:
1) Improve the safety production level, technical management level and
power supply quality of substations.
2) Make the substations easy to operate and simple to maintain, improve
labor productivity and operating efficiency, and realize the reduction of
labor and enhancement of efficiency.
3) Reduce connection between secondary devices, and save control
cables.
4) Reduce the configuration of substation equipment, avoid repeated
equipment settings, and achieve resource sharing.
5) Reduce the area of substations and the project cost.
3.0.3 The selection of the computerized monitoring and control system of
substations shall be safe, reliable, economical, advanced in technology, and
in line with nationality. Mature and reliable products that are open, extensible,
and highly resistant to interference shall be adopted.
3.0.4 The computerized monitoring and control system of substations shall
be able to realize reliable, reasonable and perfect monitoring of substations,
shall have all telecontrol functions such as telemetering, tele-signalisation,
tele-regulation, telecontrol, etc., and shall be capable of exchanging
information with the computer system of the dispatching communication
center.
3.0.5 In addition to the implementation of this Code, the design of the
computerized monitoring and control system of substations shall also carry
out relevant standards, specifications and codes, and regulations.
4 Main terms
4.0.1 Hierarchical
A way to organize elements at different levels. Among which, the elements of
the higher level have a control relationship with the elements of the lower
level.
4.0.2 Distributed
Refer to the distribution of the composition of the computerized monitoring
and control system of substations in resource logic or topology, mainly
focusing on the distribution problem on processing and distribution problem
on functions from the perspective of system structure.
4.0.3 Decentralized
Refer to the composition of the computerized monitoring and control system
of substations in terms of physical significance relative to centralization,
emphasizing the object-oriented and geographic decentralization.
4.0.4 Data acquisition
Convert all kinds of electrical quantity and status signals in the field into digital
signals that can be recognized by the computer and store in the computer
system.
4.0.5 Data processing
Systematize all kinds of data of related equipment to support the system to
complete the functions of monitoring and control, protection, control and
recording.
4.0.6 Monitoring and control
Verify whether functions are performed correctly by continuous or periodic
monitoring and control of the system or equipment, and adapt their operating
conditions to changing operational requirements.
4.0.7 Interface
Interface or connection device between two different systems or entities.
4.0.8 Communication protocol
The strict conventions necessary to initiate and maintain communication, i.e.,
a set of conventions regarding the sequence in which information is
transmitted, the format of the information, and the content of the information.
5 System composition
5.1 System structure
5.1.1 The computerized monitoring and control system of substations
should be composed of two parts: station level and bay level, and connected
by hierarchical, distributed, and open network system.
5.1.2 The station level is composed of a main unit or/and an operator station
and various functions of the computerized monitoring and control system
connected by the computer network, provides the man-machine interaction
interface running in the station, realizes the functions of management and
control of bay level equipment, forms a full station monitoring and
management center, and can communicate with the dispatching
communication center.
5.1.3 The bay level consists of several monitoring and control subsystems
connected by the industrial control network/computer network. In the case of
station level and network failure, the local monitoring and control function of
the bay equipment can still be completed independently.
5.1.4 The station level can be directly connected to the bay level or
connected via a pre-layer device. The pre-layer can communicate with the
dispatching communication center.
5.1.5 The station level equipment should be set centrally. The bay level
equipment should be decentralized in a relatively centralized manner. When
the technology is economically reasonable, it can also be set in a fully
decentralized manner or in a fully centralized manner.
5.2 Network structure
5.2.1 The station level and bay level of the computerized monitoring and
control system may adopt a unified computer network, or different networks,
respectively. When adopting a unified network, it is advisable to adopt a
network structure recommended by international standards.
5.2.2 The station level should use Ethernet recommended by international
standards. The station level system shall have good openness.
5.2.3 The bay level should adopt industrial control network, which shall
have sufficient transmission rate and extremely high reliability. Direct
communication between bay level monitoring subsystems should be realized.
5.2.4 The network topology should be either bus type or ring type, or star
type. The physical connection between the station level and the bay level
telecontrol information shall come directly from the real-time data acquired by
the bay level. Telecontrol communication equipment shall meet the
requirements of DL 5002 and DL 5003, and its capacity and performance
indicators shall meet the telecontrol function and protocol conversion
requirements of the substations.
5.3.7 The GPS timing device shall be set. The number of synchronous
pulse output interfaces and digital interfaces shall meet the system
configuration requirements, and the timing accuracy of the I/O unit shall meet
the requirements of the event sequence recording resolution.
5.3.8 The configuration quantity and performance of the printer shall be able
to meet the functional requirements of timing tabulation, call printing and
accident printing.
5.3.9 Shielded twisted pairs, coaxial cables, optical cables, or a combination
of the above several ways can be adopted for the network media. Optical
cables shall be used for long-distance communication outdoors.
5.3.10 The bay level equipment should include modules such as central
processing unit, memory, communication, and I/O control. The I/O unit shall
be configured as an electrical unit, and shall be modular, standardized, easy
to maintain and replace, allowing hot plugging.
5.3.11 When using a pre-layer device connection mode, redundant settings
shall be applied to the front-end unit.
5.3.12 The protection communication interface device can be decentralized,
and shall be able to communicate with various bay level protection devices.
5.4 Software system
5.4.1 The software of the computerized monitoring and control system of
substations shall consist of system software, supporting software and
application software.
5.4.2 The reliability, compatibility, portability, extensibility and interface
friendliness of the software system shall meet the requirements of the current
and future planning of the system.
5.4.3 The software system shall be modular in structure for easy
modification and maintenance.
5.4.4 The system software shall be a mature real-time multitasking
operating system with a complete self-diagnostic program.
5.4.5 The structure of the database shall meet the requirements of
decentralized and distributed control methods, have good maintainability, and
5.5.5 The analog-to-digital conversion resolution is not less than 12 bits,
and the maximum error shall meet the requirements of DL/T 630-1997.
5.5.6 The analog dead-band transmission time is no more than 2s (to the
station level display).
5.5.7 The on-off displacement transmission time is no more than 1s (to the
station level display).
5.5.8 The correct rate of telecontrol operation is not less than 99.99%, and
the correct rate of tele-regulation is not less than 99.9%.
5.5.9 The response time of the on-off signal input to screen display is no
more than 2s.
5.5.10 The resolution of the sequence of event (SOE) is no more than 2ms.
5.5.11 The dynamic screen response time is no more than 2s.
5.5.12 The timing accuracy error of the entire system shall be no more than
1ms.
5.5.13 For equipment installed in the main control room, the
electromagnetic immunity requirements can be referred to the general
industrial standards; and the bay level equipment and the network equipment
installed in the relay kiosk shall have immunity to this electromagnetic
environment. The immunity of the bay level equipment and network
equipment of the relay kiosk for 500kV (330kV) substations should meet the
following test level requirements:
For electrostatic discharge In line with GB/T 17626-4-2, Level 4
For radiated electromagnetic field In line with GB/T 17626-4-3, Level 3
(Level 4 required for network)
For fast transient In line with GB/T 17626-4-4, Level 4
For impact (surge) In line with GB/T 17626-4-5, Level 3
For electromagnetic induction conduction In line with GB/T 17626-4-6,
Level 3
For power frequency electromagnetic field In line with GB/T 17626-4-8,
Level 4
For pulse electromagnetic field In line with GB/T 17626-4-9, Level 5
For damped oscillating magnetic field In line with GB/T 17626-4-10,
Level 5
should be of star type.
5.2.5 When the station level and the bay level adopt the same network,
nodes should be arranged in layers or segments to meet the requirements of
network capacity and communication load rate.
5.2.6 The station level of 500kV (330kV) substations should adopt a dual
network, and run in hot standby mode, while the bay level can adopt a single
network. A single network can be used for 220kV substations.
5.2.7 The computer network of substations shall have the ability to connect
with the national power data network, and realize the remote transmission of
dispatching automation, protection, management and other information within
the substations as required.
5.3 Hardware equipment
5.3.1 The hardware equipment of the computerized monitoring and control
system of substations should be composed of the following parts:
1) Station level equipment: Include the main unit or/and operator station,
engineer station, telecontrol communication device, interface with
electric energy billing system, public interface, etc.;
2) Network equipment: Include the network connection device,
optical/electrical converter, interface device and network connections,
cable, optical cable, etc.;
3) Bay level equipment: Include the I/O unit, control unit, bay level network,
interface with station level network, relay protection communication
interface device, etc.
5.3.2 The main unit configurations of the station level shall meet the
functional requirements and performance indicator requirements of the entire
system. The main unit capacity shall be compatible with the planned capacity
of the substation. Products with excellent performance and in line with
industrial standards shall be selected.
5.3.3 The operator station shall meet the requirements of the operator for
intuitive, convenient, safe and reliable operation.
5.3.4 The main unit should be configured in a dual-unit redundancy.
5.3.5 500kV (330kV) substations should be equipped with dedicated
engineer stations, while 220kV substations may not be equipped with
dedicated engineer stations.
5.3.6 Two sets of telecontrol communication equipment shall be set up. The
6 System functions
6.1 Data acquisition and processing
6.1.1 The computerized monitoring and control system of substations shall
enable data acquisition and processing functions, including analog quantities,
on-off quantities, electrical energy, and data from other intelligent devices.
6.1.2 Analog acquisition includes the signals of current, voltage, active
power, reactive power, power factor, frequency, and temperature.
6.1.3 On-off acquisition includes the position signals of breaker, isolation
switch and grounding switch, action and alarm signal of relay protection
device and automatic safety device, operation monitoring signal, and on-load
tap changing transformer tap position signal.
6.1.4 Electric energy harvesting shall include active energy and reactive
energy data, and can achieve functions such as time-sharing accumulation
and energy balance.
6.1.5 For the on-load tap changing transformer tap position signal
equivalent, it is advisable to use a hard-wired point-to-point acquisition
method, and BCD codes or analog acquisition method can be used.
6.1.6 For the analog quantity collected in real time, the validity check and
corresponding processing shall be carried out. For the on-off quantity
collected in real time, filtering shall be performed to eliminate contact jitter.
6.1.7 The various information acquired through the data communication
interface shall be processed separately.
6.2 Database establishment and maintenance
6.2.1 The computerized monitoring and control system of substations shall
establish a real-time database to store and continuously update all real-time
data from the I/O units and communication interfaces.
6.2.2 The computerized monitoring and control system of substations shall
establish a historical database to store and regularly update historical data
and operation report data that need to be saved.
6.2.3 The data in the historical database shall be easily selected and
combined as needed, dumped to a disc, and stored for a long time.
6.2.4 The database shall be able to perform online maintenance, add,
reduce, and modify data items.
required, including the automatic switching reactive power compensation
equipment and main regulating transformer tap position.
6.3.9 Automatic control of voltage and reactive power shall fully consider the
requirements of operation mode and various locking conditions.
6.3.10 Sequence control and regulation control function management shall
be relatively independent. It can be put in/out from the operation staff without
affecting normal operation.
6.3.11 In the process of automatic control, if the program encounters any
software or hardware faults, it shall output alarm information, stop the control
operation, and maintain the state of the controlled equipment.
6.4 Anti-mislocking
6.4.1 All operation controls shall be protected against mislocking, along with
error alarm and judgment information output.
6.4.2 The station level shall realize the integrated operation locking function
for all equipment in the substation. The bay level shall realize the operation
locking function of each electrical unit equipment.
6.4.3 For manual operation of the isolation switch and grounding switch, the
coded lock shall be adopted to prevent misoperation, or the electromagnetic
lock can be adopted, and the electric lock should be set in the local control
box. All operations shall be managed with permission levels.
6.4.4 The anti-misoperation mode of the station level is mainly based on all
comprehensive information for logical judgment and locking. The
anti-misoperation of the bay level is combined with real-time status detection,
logic judgment and output circuit locking to fully guarantee various safety
requirements for the primary equipment of this unit.
6.4.5 The judging criteria and conditions for anti-mislocking shall comply
with the relevant codes, specifications and operational requirements of the
“five antis”.
6.4.6 The anti-mislocking and locking logic shall be modified after
authorization.
6.5 Synchronizing
6.5.1 The computerized monitoring and control system shall have a
synchronizing function to meet the synchronous closing and reclosing
synchronous locking requirements of the breaker.
6.5.2 The synchronizing function should be completed at the bay level.
values from 1 min before the disturbance to 2 min after the disturbance. The
sampling period is consistent with the real-time system sampling in the same
period.
6.8 Screen generation and display
6.8.1 The computerized monitoring and control system shall have the ability
for users to edit and generate images, and the method is simple.
6.8.2 The information displayed on the screen shall include: calendar time,
numbered measurement points, text or graphics representing the point,
real-time data or historical data of the point, various parameters after
operation or combination, etc.
6.8.3 The screen generation shall be able to define all the sampling points,
time scales, sampling periods and other parameters in the database.
6.8.4 The information displayed on the screen should include: electrical
wiring diagram, equipment configuration diagram, operation condition
diagram, various information reports, operation tickets and various operation
reports required for the production and operation of the whole substation.
6.8.5 The text display of all application screens shall be in Chinese.
6.8.6 The screen displayed can be copied or duplicated by a printer for
output.
6.9 Online calculation and tabulation
6.9.1 Online calculations shall include engineering calculations of raw data
for various electrical quantities acquired.
6.9.2 Statistical calculations shall be made for various conventional
parameters of the substation operation, such as maximum and minimum of
day, month and year and their time of occurrence, voltage qualification rate,
transformer load rate, load and electric energy balance rate of the whole
substation, etc.
6.9.3 Statistical calculations shall be made for the operation status of the
main equipment of the substation, such as normal operation and number of
accident trips of the breaker, main transformer tap regulation levels and times
and their outage time and times, etc.
6.9.4 Optimizing calculation shall be made for the scheme of the automatic
control operation of the substation, and statistical calculations shall be made
for its operation results.
6.9.5 The computerized monitoring and control system shall be able to
telecontrol communication equipment.
6.12.2 In the computerized monitoring and control system of substations,
the error between each bay level subsystem and the GPS standard clock
shall be no more than 1ms.
6.12.3 When the telecontrol communication equipment is normal, the clock
is corrected by GPS, and it can also be timed with the dispatcher when
needed.
6.12.4 When the computerized monitoring and control system equipment is
more centralized, it is better to configure a set of satellite clock signal
receiving devices with sufficient output capability. When it is more
decentralized, the local decentralized configuration can be adopted.
6.13 Man-machine interaction
6.13.1 The operator station shall be the main interface for the computerized
monitoring and control system of substations to contact the operators. The
local control of the bay level is the alternate interface in the emergency
situation.
6.13.2 The man-machine interaction provided by the operator station for the
operators shall include: calling, displaying and copying various graphics,
curves, and reports; issuing operation control commands; viewing historical
values and various definite values; generation and modification of graphics
and reports; alarm validation, and exit/recovery of alarm points; display,
online editing and printing of operation tickets; and editing and preparation of
operation files.
6.13.3 The engineer station is the main interface for the computerized
monitoring and control system of substations to contact the full-time
maintenance personnel. The man-machine interaction it shall provide
includes: database definition and modification, parameter definition and
modification of various applications, secondary development when needed,
and other functions on the operator station.
6.13.4 The local control of the bay level shall provide the display of a few
important parameters and operation buttons. Permissions and passwords
shall be set for internal access (e.g., database maintenance, parameter
settings, etc.) to all kinds of operation and monitoring system to ensure the
system security.
6.13.5 All modifications to the data, procedures, parameters, etc. of the
computerized monitoring and control system shall be recorded.
7 Signal input/output
7.1 Analog input signal
7.1.1 The analog quantity should be acquired by AC sampling.
7.1.2 When the AC sampling mode is adopted, the current of the current
transformer and the voltage of the voltage transformer of each installation
organization controlled shall be collected. DC sampling can be adopted for
DC bus voltage, temperature and other non-electrical signals. The sampled
parameters shall meet the requirements of the computerized monitoring and
control system to obtain the measured parameters described in Appendix B
through calculation and accumulation.
7.2 On-off input signal
7.2.1 The on-off signal should adopt the passive contact input mode. For
the device to be controlled, the on-off signal should adopt the double contact
input mode.
7.2.2 The alarm and action signals of digital relay protection and safety
automatic devices should adopt the input mode of communication interface.
Signals for other relay protection and safety automation devices can also be
input in a hardwired manner.
7.2.3 The on-off input interface shall adopt photoelectric isolation and surge
absorption circuits. A strong electrical input module shall be adopted for
signal circuits with poor electromagnetic environment.
7.2.4 See Appendix C for the on-off input signals of each installation
organization.
7.3 Electrical energy data input signal
7.3.1 The electric energy data acquisition method should adopt a smart
electric energy meter to input in serial communication mode. When pulse
input mode is adopted, anti-interference measures shall be taken. When the
technical conditions permit, the electric energy data can also be obtained by
secondary conversion of the collected current and voltage signals.
7.3.2 For the electric energy metering points already included in the
......
......
| Standard ID | DL/T 5149-2020 (DL/T5149-2020) | | Description (Translated English) | Code for design of substation monitoring and control system | | Sector / Industry | Electricity & Power Industry Standard (Recommended) | | Classification of Chinese Standard | P62 | | Classification of International Standard | 29.240 | | Word Count Estimation | 69,639 | | Date of Issue | 2020-10-23 | | Date of Implementation | 2021-02-01 | | Older Standard (superseded by this standard) | DL/T 5149-2001 | | Quoted Standard | GB/T 17626.2; GB/T 17626.3; GB/T 17626.4; GB/T 17626.5; GB/T 17626.6; GB/T 17626.8; GB/T 17626.9; GB/T 17626.10; GB/T 17626.11; GB/T 17626.12; GB/T 25931; GB 50217; DL/T 634.5104; DL/T 860; DL/T 1404; DL/T 1708; DL/T 5002; DL/T 5003; DL/T 5044; DL/T 5136 | | Summary | This standard is applicable to the design of monitoring system of 110(66) kV��1000kV newly built, expanded or rebuilt substation (switch station). The substation monitoring system should adopt products with good openness, easy expansion, strong anti-interference, and mature and reliable products. On the basis of ensuring reliable operation, new technologies and new equipment can be actively and steadily adopted in combination with engineering characteristics. The substation monitoring system should be able to monitor, measure and control the substation, and should have telemetry, remote signaling, remote adjustment and remote control functions, and the ability to cooperate and interact with the dispatch control center. The design of the substation monitoring system shall not only conform to the requirements of this standard, but also conform to the current state of the country. |
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