Download Technical recommendation for the purchase of EAVC for HV systems

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CLNR-L209
Date of Issue: December 2014
1
Technical recommendation for the
purchase of Enhanced Automatic Voltage
Control for HV systems
1. Purpose
The purpose of this document is to set out and describe the technical requirements developed, that
enabled the purchase of the various Enhanced Automatic Voltage Control schemes applied on the
Northern Powergrid High Voltage power distribution networks that were trialled on the Customer-Led
Network Revolution project.
2. Scope
This recommendation details the technical requirements for all equipment to be used in the enhanced
automatic control of voltage at High Voltage networks.
The document applies to:
 Primary transformers that have a primary winding operating at Extra High Voltage (greater than
30 kV but less than 100 kV); and their secondary windings at High Voltage (greater than 1 kV
but less than 30 kV);
 HV Switched capacitor banks i.e. greater than 1kV but less than 30kV;
 HV in-line voltage regulators
The document applies to all equipment involved in the control of an OLTC, switched capacitor bank or
in-line voltage regulator including its ability to accept communication links with external systems.
This recommendation includes the interfacing requirements with a remote controller called the Grand
Unified Scheme (GUS) as part of the Customer-Led Network Revolution (CLNR) project. The use of the
EAVC in the CLNR project is to demonstrate its interaction with other smart grid solutions and control of
the network voltage.
A summary table of the supplier/product technical compliance is given in Appendix 1 - 6 for
manufacturers to complete, detailing specifics about their offers and any variations from this standard.
Manufacturers are encouraged to offer more than one option if they have a number of possible solutions
to the overall functionality of the EAVC scheme.
The Technical Requirements detailed in the main body of this document are designed to be functionally
generic, so that other possible solutions are not over looked. Additional site specific data will be
discussed with the potential supplier.
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Document Reference:
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Date of Issue: December 2014
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Contents
1.
PURPOSE ............................................................................................................................................................... 1
2.
SCOPE .................................................................................................................................................................... 1
2.1
2.2
3.
CONTENTS...................................................................................................................................................................2
COMPONENTS ..............................................................................................................................................................4
TECHNICAL REQUIREMENTS.............................................................................................................................. 5
3.1
GENERAL REQUIREMENTS...............................................................................................................................................5
3.1.1
Service Conditions ............................................................................................................................................5
3.1.1.1
3.1.1.2
3.1.1.3
3.1.1.4
3.1.1.5
3.1.1.6
Indoors ...........................................................................................................................................................................5
Outdoors ........................................................................................................................................................................5
Degrees of Protection ....................................................................................................................................................5
Marking and Labelling....................................................................................................................................................6
Small Wiring and Terminal Blocks ..................................................................................................................................6
Equipment Location .......................................................................................................................................................7
3.2
OPERATING CHARACTERISTICS .........................................................................................................................................7
3.2.1
Essential inputs ................................................................................................................................................7
3.2.2
Desirable but not Essential Inputs ....................................................................................................................8
3.2.3
Essential Outputs .............................................................................................................................................8
3.2.4
Desirable but not Essential Outputs .................................................................................................................9
3.2.5
GUS Inputs .......................................................................................................................................................9
3.2.6
Essential Functionality .....................................................................................................................................9
3.2.7
Desirable but no Essential Functionality ........................................................................................................12
3.3
COMMUNICATIONS .....................................................................................................................................................12
3.3.1
Electromagnetic Compatibility .......................................................................................................................13
3.4
OPERATING ENVIRONMENT ..........................................................................................................................................13
3.4.1
Local Controllers ............................................................................................................................................14
3.5
INSTALLATION, OPERATION AND MAINTENANCE ...............................................................................................................14
3.5.1
Installation .....................................................................................................................................................14
3.5.2
Indicators .......................................................................................................................................................15
3.5.3
Alarms ............................................................................................................................................................15
3.5.4
Earthing of Enclosure Cubicles .......................................................................................................................15
3.5.4.1
Earthing of Small Apparatus and Equipment ...............................................................................................................16
3.5.5
Maintenance ..................................................................................................................................................16
3.6
TRAINING REQUIREMENTS ............................................................................................................................................16
3.6.1
OLTC at Primary Substations..........................................................................................................................16
3.6.2
Switched Capacitor Bank ...............................................................................................................................16
3.6.3
In-line Regulator ............................................................................................................................................16
3.7
SUPPORT AND DEVELOPMENT REQUIREMENTS .................................................................................................................16
4.
WEEE REGULATIONS ......................................................................................................................................... 17
5.
REFERENCES ...................................................................................................................................................... 17
5.1
5.2
5.3
6.
EXTERNAL DOCUMENTATION ........................................................................................................................................17
INTERNAL DOCUMENTATION .........................................................................................................................................18
SUMMARY OF AMENDMENTS ........................................................................................................................................19
DEFINITIONS........................................................................................................................................................ 20
APPENDIX 1A – SCHEDULE OF SUPPLIERS TECHNICAL DATA .......................................................................... 20
APPENDIX 1B – SCHEDULE OF SUPPLIERS TECHNICAL DATA – LOCAL CONTROLLER ................................ 22
APPENDIX 1C – SCHEDULE OF SUPPLIERS TECHNICAL DATA – EAVC ANCILLARY EQUIPMENT ................ 24
APPENDIX 1D – SCHEDULE OF SUPPLIERS TECHNICAL DATA – COMPLIANCE WITH SPECIFICATION ....... 25
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Document Reference:
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APPENDIX 2A – SELF CERTIFICATION CONFORMANCE DECLARATION – TABLES 1-9 OF THIS
SPECIFICATION .......................................................................................................................................................... 26
APPENDIX 2B – SELF CERTIFICATION CONFORMANCE DECLARATION ........................................................... 28
APPENDIX 2C – ENA TS 50-18 TYPE TEST SELF CERTIFICATION CONFORMANCE DECLARATION .............. 31
APPENDIX 3 – ADDENDUM TO SUPPLIER REQUIREMENTS................................................................................. 36
APPENDIX 4 – PRE-COMMISSION TESTING, ROUTINE INSPECTION AND MAINTENANCE
REQUIREMENTS ......................................................................................................................................................... 37
APPENDIX 5 – TECHNICAL INFORMATION CHECK LIST ....................................................................................... 38
APPENDIX 6 – SCHEDULE OF COMPONENTS ........................................................................................................ 39
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Document Reference:
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Date of Issue: December 2014
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2.1 Components
1
2
3
4
5
6
7
8
9
10
11
12
Figure 1 - Components of an EAVC Scheme
19” Rack Cabinet
Local Controller
Communications Link
Manual/Auto Switch
Supervisory/Remote Switch
GUS/Remote switch
Tap Up button
Tap Down button
Test Block
Static Over Voltage Relay
Reset Button
Fuses
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Date of Issue: December 2014
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3. Technical Requirements
This section gives the technical requirements of the EAVC scheme installed on HV networks.
The recommendation illustrates the scope and accuracy required, however if manufacturers can offer
other cost effective solutions that deliver the same outcomes by other means these should be
considered. Manufacturers should detail additional functions, highlight any savings or justify the
additional expenditure.
The following schemes’ components and their properties are illustrated in the following Tables:









Table 1 illustrates the essential inputs of the local controller
Table 2 illustrates the desirable but not essential inputs of the local controller.
Table 3 illustrates the local controller’s data outputs.
Table 4 illustrates the local controller’s desirable but not essential data outputs.
Table 5 illustrates the expected inputs from the GUS
Table 6 illustrates the local controller’s essential functionality
Table 7 illustrates the essential functionality of the other EAVC components.
Table 8 illustrates the local controller’s desirable but not essential functionality.
Table 9 illustrates the operating environment for the Local controller
If manufacturers cannot meet a specification, they should indicate how close to the requirement they can
achieve.
Various systems, with which the EAVC solution may need to interact, may develop over the next few
years with various possible approaches. It is therefore attractive that a solution is flexible and can
integrate with a range of other technologies and software platforms.
3.1 General Requirements
The individual components and mounting cubicles detailed in clause 2.2 should be designed and
tested to be compliant with ENA TS 50-18 except where detailed separately within the body of this
recommendation.
3.1.1
Service Conditions
The EAVC scheme will use equipment designed for use in both indoor and outdoor environments.
3.1.1.1
Indoors
Typically a brick built housing; this will provide protection from the direct effects of most elements of
the weather, but is not usually temperature maintained, or climate controlled. Indoor units should be
capable of continued operation whilst exposed to ambient temperatures with a minimum of -5°C.
3.1.1.2
Outdoors
Open to the direct effects of all-weather elements and climatic effects.
Outdoor units should be capable of continued operation whilst exposed to ambient temperatures
with a range of -25°C to 55° (to allow for the effect of solar radiation on the equipment). Any
equipment intended for external operation shall be UV stable with testing carried out in accordance
with BS 2782-5:Method 552A:1999.
3.1.1.3
Degrees of Protection
All equipment used by the EAVC should be compliant with ENA TS 50-18 clause 4.2.2 and be
environmentally tested to the following minima:
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 IP31 rating for indoor equipment;
 IP54 rating for outdoor equipment
All IP ratings are in accordance with BSEN 60529.
3.1.1.4
Marking and Labelling
The EAVC enclosures should be marked in accordance with clause 5.10 of IEC 62771-1.
All equipment and apparatus should be labelled in accordance with clause 5.4.4.4 of IEC 62271-1
and the following:
Labels should be provided where instruction, explanations or warning are appropriate to the
operation or maintenance of the equipment.
Circuit identification labels, secured with screw fixings, should be provided on the front of the EAVC
door and at the back where rear access is provided. Where identification labels are fixed to doors
an identical label should be provided internally on the fixed portion, at a point that is clearly visible.
Safety warning labels should comply with BS ISO 3864-1:2011.
All labels should be suitably rated for the environment conditions and last the lifetime of the
equipment to which they apply.
The function and rating of fuses and MCB’s should be marked adjacent to the device.
All identification markings should be unambiguously associated with the relevant equipment and
should be clearly visible from normal viewing angles of the equipment.
Equipment wire end terminations should be identified using permanent Alpha-Numeric local end
marking. All wiring within the enclosure should be fully compliant with ENA TS 50-19.
3.1.1.5
Small Wiring and Terminal Blocks
All small wiring should comply with Clause 5.4.4.5.1 of IEC 62271-1 and ENA TS 50-18 issue 3,
clause 5.1 with the following exceptions:
CT and VT Wiring
DC Wiring
AC Wiring (110V)
AC Wiring (240V)
Pilot Wiring
-
Phase Colour (Red, Yellow, Blue and Black)
Grey
Black
Black (Double Insulated)
Black (5kV Insulated up to 66kV and 15kV over 66kV)
Small wiring cable should be single core multi-stranded, copper conductor, PVC insulated and
compliant with BS 6231. In the interest of mechanical strength, the nominal minimum conductor
size shall be 1.5mm² for applications e.g. SCADA, where smaller sizes are appropriate, their use
should be the subject to agreement with the project engineer.
Current transformer secondary connections should have a minimum conductor cross sectional area
of 2.5mm²
Terminal blocks and terminations should comply with the relevant provisions detailed in IEC 622711 clause 5.4.4.5.2, BSEN 60947-7-1 and ENA TS 50-18 issue 3 clause 5.2.1 and 5.2.2. They
should generally be either screw or stud type for use with an approved ring type crimped
termination or spring loaded insertion type incorporating an approved hook type crimped connector.
Telecontrol / SCADA Terminal Blocks
1.5mm SAKR or equivalent
AC/DC Terminal Blocks
2.5mm RSF3 or equivalent
CT/VT Terminal Blocks
6.0mm RSF1 or equivalent
Buswiring and Supply Terminal Blocks (J1/J2)
6.0mm RSF1 or equivalent
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All terminal blocks should be grouped on the terminal rails in the above order from the top of the rail
to the bottom. Bus wiring terminal blocks should be located at the top of the panel and labelled
accordingly.
3.1.1.6
Equipment Location
The required components of an EAVC scheme are listed below with their locations and associated
product specifications where available.




Measurement Devices – Outdoor (Metering/protection Voltage Transformer (VT) to
Northern Powergrid Specification - NPS/003/001 and Current Transformer (CT) to
Northern Powergrid Specification -NPS/003/023 – used as part of the essential inputs of
the local controller, however the monitoring devices are not part of the scope of this
document;
Actuators – Outdoor/indoor – used as part of the essential inputs and outputs of the local
controller’s input and output signals, however the actuators are not part of the scope of this
document;
Local Controllers – Indoor (sub-station’s control room);
Communications - Indoor and Outdoor according to requirements.
Substation
Where appropriate, equipment should be located in a substation fitting into a standard 19” rack.
3.2 Operating Characteristics
The measurement devices are either, the equipment’s integral VT and CTs or the
metering/protection VT and CTs already installed as part of the substation metering and protection
systems.
The measurement devices should be able to measure and output data to the recommendation
given in Table 1 to Table 4.
Note: For a switched capacitor bank with 3 capacitors (A, B & C), the local controller should only be
able to connect one capacitor to the network at a time; therefore the switched capacitor bank will
have 4 switching position maps that the local controller will need to replicate in response to a
change of voltage request:
1. A – off, B – off, C – off;
2. A – on, B – off, C – off;
3. A – off, B – on, C – off;
4. A – off, B – off, C – on.
3.2.1
Essential inputs
Table 1 Local Controller Essential Input Signals
Type
Sending Device
Type
Other
Voltage
VT
Class ‘S’ or better
as specified in
IEC 61000-4-30
The local controller shall be capable of operating
with VTs with outputs of between 63.5 and 250V.
Current
CT
Class ‘S’ or better
as specified in
IEC 61000-4-30
The local controller shall be capable of operating
with CTs of 1 or 5A secondary rating. The local
controller shall be able to accept non-standard
CT ratios to be used through configurable inputs.
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Document Reference:
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Tap or Switch
Position
OLTC / Capacitor
Bank
Voltage Signal /
Data
Communications
8
OLTC –The local controller shall be capable of
measuring up to a minimum of 39 tap positions
(for distribution OLTC) and 12 tap positions (for
in-line regulator OLTC) using Resistor Chain,
Binary, Binary Coded Decimal or Grey Code
sender units.
Capacitor Bank –The local controller shall be
capable of detecting the switch configuration of
the capacitor bank.
Voltage reduction
SCADA
Data
Communications
Voltage Setpoint
GUS
Data
Communications
Supervisory/Remote
Supervisory/Remote
Switch
Voltage Signal
GUS/Remote
GUS/Remote Switch
Voltage Signal
Manual/Auto
Manual/Auto Switch
Voltage Signal
Tap or Raise Up
Tap/Raise Up button
Voltage Signal
Tap or Lower Down
Tap/Lower Down
button
Voltage Signal
3.2.2
The local controller shall be able to accept a
signal from a SCADA RTU to reduce the system
voltage in compliance with the voltage reduction
scheme.
The Manufacturer is required to detail, how the
local controller will alter its setpoint from a signal
received over a communications link.
Manual two position switch that selects
‘Supervisory’ or ‘Remote’ Mode. Supervisory will
enable the local controller to work in automatic
mode but send and receive communications from
SCADA. Remote enables the local controller to
operate automatically and blocks all
communications to SCADA.
Manual two position switch that selects ‘GUS’ or
‘Remote’ mode. GUS enables the local controller
to operate automatically and accept its setpoint
via a communications link. Remote enables the
local controller to operate automatically and block
all communications to the ‘GUS’.
Manual two position switch that selects ‘Manual’
or ‘Automatic’ Mode
The ‘Tap/ Up’ / ’Raise volts’ button shall only be
operable if the Manual/Auto switch is in the
Manual’ position.
The ‘Tap/ Down’ / ’Lower volts’ button shall
only be operable if the Manual/Auto switch is in
the ‘Manual’ position.
Desirable but not Essential Inputs
Table 2 Local Controller Desirable Input Signals
Type
Sending Device
Type
Other
Feeder Current
Feeder metering position
Class ‘S’ or better as
specified in IEC
61000-4-30
To help estimate the amount of
distributed generation on each
feeder.
3.2.3
Essential Outputs
Below is a list of the minimum outputs that the local controller should be capable of sending to
another device, these may be calculated or measured directly.
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Table 3 Local Controller Desirable Input Signals
Type
Tap Up/Raise Volts
To
Type
Other
OLTC/Capacitor Bank
Voltage signal/ Data
signal
Raises the secondary voltage by
tapping the OLTC up one
tap/switched the capacitor bank
accordingly to raise the network
voltage.
Tap Down/Lower
Volts
OLTC/Capacitor Bank
Voltage signal/ Data
signal
Lowers the secondary voltage by
tapping the OLTC down one tap/
switched the capacitor bank
accordingly to lower the network
voltage.
Block
Internal
None
Stops “tap runaway” by blocking
all tap/switching operations
Alarms
User Interface, The GUS,
SCADA
Voltage signal/ Data
signal
Secondary Voltage
The GUS
Data Signal
Secondary Current
The GUS
Data Signal
3.2.4
Desirable but not Essential Outputs
Table 4 lists the outputs that are desirable to be sent to a remote position but not essential.
Table 4 Desirable Data Outputs
Type
To
Type
Estimated Generation
The GUS
Data Signal
3.2.5
Other
GUS Inputs
Table 5 is a list of the inputs that the system should be able to receive.
Table 5 Expected Signals from GUS
Type
To
Type
Frequency
Handshake/Heartbeat
Local Controller
Data
1 minute
Setpoint check/Change
Local Controller
Data
1 minute
3.2.6
Essential Functionality
Table 6 Local controller Essential Functionality
The local controller should be of the solid state/microprocesor type and have a true RMS
measuring circuit supplied from a nominal 110V AC VT supply.
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Essential Inputs
Description
Function
VT Monitoring
The VT is constantly monitored and its ratio errors shall be considered and eliminated with
adjustment.
CT Monitoring
The CT is constantly monitored and shall not be dependent on its connected phase for its
compatibility.
Control Outputs
Description
Function
Raise signal
Determine that a tap operation/raise in voltage is required and send a signal to the OLTC to
tap up/to the capacitor bank to switch accordingly. 
Lower signal
Determine that a tap operation/lowering in voltage is required and send a signal to the OLTC
to tap down/to the capacitor bank to switch accordingly.
Status Checks
Description
Function
Auxiliary Voltage
110v panel auxiliary supply monitor.
Line Voltage
The local controller shall provide a permanent display of the primary line voltage in kV to one
decimal place (This can be provided discreet or integral to the controller).
Metering
The local controller shall provide a selectable digital display of power factor to two decimal
places, and three phase balanced power using three voltages and one current input.
Tap Lock
Prevents “tap runaway” by disabling the local controller from performing any tap
change/switch operations.
Tap Change Master Operated from the runaway protection which must require to be reset by hand before further
operations can be carried out. Indication of operation shall be provided. The runaway
Lock Out Feature
prevention scheme shall also prevent runaway in the event of a raise contactor sticking in.
Tap/Switch Position
The local controller shall be able to determine the Tap position/capacitor bank switch
configuration and permanently display it with a collection of suitable indicators; this may be
provided discreet or integral to the controller. The indicators shall be suitably labelled to avoid any
ambiguity. Additionally the system shall provide a tap change in progress indication lamp.
OLTC/Capacitor Bank There shall be a tap change/capacitor bank variable that is incremented each time the
operation
OLTC/capacitor back is operated.
Self-supervision
Signal
The local controller shall constantly monitor itself for correct operation and any error shall be
sent as an alarm and an indicator on the user interface.
Overcurrent Blocking
Stops any operation if excessive load is detected.
Overvoltage Blocking
Prevents ‘Tap Up’ operations if a pre-set value is or will be breached by the tap/switching
operation. ‘Tap Down’ operations are not blocked.
Undervoltage
Blocking
Prevents ‘Tap Down’ operations if a pre-set value is or will be breached by the tap/switching
operation. ‘Tap Up’ operations are not blocked.
Locking Policy
Operating switches shall accept a safety locking policy requirement.
Tap Freeze Function
A ‘Tap Freeze’ switch to be implemented whilst retaining relay power. When turning to
Manual Mode a notification shall be displayed to communicate the ‘tap freeze’ status.
External Inputs
Description
Function
Manual Mode
Determines the setting of the Manual/Auto switch and when selected to ‘Manual’ only tap
operations via the ‘Tap Up’/’Raise Volts’, ‘Tap Down’/’Lower Volts’ buttons on the 19 inch
rack cabinet will be carried out.
Automatic Mode
Determines the setting of the Manual/Auto switch and when selected to ‘Auto’ only automatic
tap operations via the local controller will be carried out. The ‘Tap Up’/’Raise Volts’, ‘Tap
Down’/’Lower Volts’ buttons on the 19 inch rack cabinet will be disabled.
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Supervisory Mode
Allows SCADA to monitor the local controller and apply the voltage reduction scheme when
required. This mode shall also provide the ability to take the voltage controller between Auto
/ Manual mode via the SCADA control providing a ‘Tap Freeze’ function.
Reduce set voltage
(-3% -6%)
The ‘Grid Code’ voltage reduction will instantly drop the current voltage by 3 or 6 percent. The
local controller will be restricted from compensating for the reduction. Additionally, for OLTC, a
facility shall be provided to remotely bring either transformer to unity power factor.
External Functions
Accept a setpoint over a communications link.
Hold a default setpoint.
Load Drop Compensation (LDC) – equation that calculates the theoretical voltage drop along a circuit with a known
load. Must be available, with a variable range of at least 0 – 10%. The CT rating for LDC input shall be user
selectable for either 1A or 5A and have a continuous rating of 1.3 times nominal.
Mode 1 – Calculate the target Voltage from the default setpoint using Load Drop Compensation, a method of
reducing circulating current and whether there has been any voltage reduction applied by the control room.
Mode 2 – Calculate the target Voltage from the setpoint via a communications link without using Load Drop
Compensation; but applying a method of reducing circulating current and whether there has been any voltage
reduction applied by the control room.
Detect the handshake/heartbeat from the GUS and automatically switch between modes 1 and 2 depending on its
presence:
 Mode 1 = No handshake/heartbeat
 Mode 2 = Handshake/heartbeat present
Runaway Protection – Initiates a tap change master lock out to prevent tap runaway. Once operated it shall only be
reset by hand operation.
Time Delay 1 – operates once the voltage goes outside a given limit. If the voltage fluctuation is transient the delay
will reset. Minimum 0-120 seconds.
Time Delay 2 – after a tap change operation time delay 2 will start to allow for transient voltages. Minimum 0-120
seconds.
Inter Tap Delay – Minimum 0-10 seconds.
For OLTC – A method of reducing the amount of circulating current between paralleled transformers. The parallel
coupling control method shall cover a variable range of transformer impedances up to at least 30%.
For Capacitor Bank – Transient Free Switching – a method of transient free switching such as ‘Zero voltage
crossing’.
For Capacitor Bank – Hold a map of switching patterns that ensures the correct switching of capacitors for each
MVAr injection stage.
Table 7 EAVC Ancillary Equipment Essential Functionality
Essential Inputs
Description
Function
Static Overvoltage Relay
A Static Over Voltage relay should be installed on the panel which is separate to the
main voltage controller and is designed to lockout the tap changer if an overvoltage
condition is detected
Reset Button
Resets the static over voltage relay. This action can only be carried out manually.
Two position integral or discrete (‘ODS’ type) switch that a user can operate to place
the local controller in:
Supervisory/Remote Switch

Supervisory Mode – enables the SCADA link for the local controller to
communicate with SCADA for monitoring and instructional purposes. A
SCADA instruction will override all other instructions.

Remote Mode – Disables the SCADA link so that no communications are
passed from the local controller to SCADA and vice versa.
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Two position integral or discrete (‘ODS’ type) switch that a user can operate to place
the local controller in:

GUS Mode – enables the GUS link for the local controller to
communicate its local inputs to the GUS; plus the GUS can set the
local controller’s setpoint.

Remote Mode – Disables the GUS communication link so that no
communications are passed from the local controller to the GUS and vice
versa.
GUS/Remote Switch
Two position integral or discrete (‘ODS’ type) switch that a user can operate to
place the local controller in either 'Manual' mode or ‘Automatic' mode.

Manual/Automatic Switch
Manual Mode – disables the local controller from operating the OLTC when
there is a voltage excursion from the pre-set voltage bandwidth; enables the
‘Tap Up’/’Raise Volts’ and ‘Tap Down’/’Lower Volts’ buttons.

Automatic Mode – enables the local controller to automatically operate the
OLTC when there is a voltage excursion from the pre-set voltage
bandwidth; disables the ‘Tap Up’/’Raise Volts’ and ‘Tap Down’/’Lower Volts’
buttons.
A push button biased switch that, when pushed, sends a voltage signal to the local
controller to, which raises the network voltage by operating the OLTC ‘Up’ one
‘Tap Up’/’Raise Volts’ button
position/switching the capacitor bank accordingly. The voltage will only be raised if
the button is enabled (Manual Mode) and the OLTC/Capacitor Bank is not at its top
limit.
A push button biased switch that, when operated, sends a voltage signal to the
local controller, which lowers the network voltage by operating the OLTC ‘Down’ one
‘Tap Down’/’Lower Volts’ button position/switching the capacitor bank accordingly. The voltage will only be lowered
if the button is enabled (Manual Mode) and the OLTC/Capacitor Bank is not at its
lower limit.
Voltage take off requirement for A direct reference upstream the outgoing LV fuses at the primary substation shall
be provided to LV board, in addition to the voltage and reference provided
LV board direct reference
downstream the fuses.
19” Rack Cabinet
3.2.7
Free standing 19” rack
Desirable but no Essential Functionality
Table 8 Local Controller Desirable Functionality
Essential Inputs
Description
Function
Estimated Generation Estimate the generation connected to the network
3.3 Communications
Communications are required for EAVC components between:
 The measurement devices and the local controller,
 The local controller and a SCADA RTU, and
 The local controller and the GUS.
The individual sites at which the EAVC equipment will be installed are Primary Substations or
locally on the regulator. Therefore the measurement devices will already be installed a) as part of
the substation’s protection/metering systems or b) fitted on the regulator. A manufacturer should
indicate if they have a solution that uses different monitoring equipment to the standard
protection/metering transformers.
Manufacturers should also confirm what the communications media for the three categories are. It
is expected that the communications media that should be used are:
 Between Measurement Devices and Local Controller – hardwired link;
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
Between the local controller and a SCADA RTU– standard LAN (i.e. a hardwired link for
local communications);
 Between the local controller and the GUS – ADSL (i.e. fast communications over fixed
lines), GPRS (i.e. cellular communications) or standard LAN (i.e. a hardwired link for local
communications).
If manufacturers use a different communication media, they should give evidence that they achieve
a similar level of performance.
The local controller and a GUS controller may be housed in the same facility e.g. the Primary
substation control room. In which case communicating between the two systems could be via an IP
based LAN (i.e. a hardwired link for local communications). Should the GUS controller be installed
at another location, then a robust communication media must be provided.
By any means, the local controller should be able to detect a loss of communication to the GUS,
and depending on this connectivity operate in one of two modes:
 Mode 1 will be will full communications with the GUS – the control module will use the
voltage set point from the GUS communications.
 Mode 2 is where communications with the GUS have failed – the control module will use
its default voltage set point and use Load Drop Compensation in its nominal voltage
calculation.
It is desirable that devices can use as many different types of communication media as possible for
flexibility. The types of communication protocols required are given in Table 9. Further work with
the manufacturer will be required to agree the format of data.
In all cases all GPRS communications equipment must be compliant with the EMC requirements
given in clause 3.3.1.
3.3.1
Electromagnetic Compatibility
Communications GPRS Electromagnetic Compatibility Tests for the communication
equipment.
All equipment should be compatible with the following generic EMC standards:
BS EN 61000-6-3: 2007 - Generic Emissions standard
BS EN 61000-6-2: 2005 - Generic Immunity standard
BS EN 61000-4-2: 2009 - Electrostatic discharge immunity Test ((Requirement Air 8kV, Contact
4kV)
BS EN 61000-4-3: 2006 Radiated radio Frequency, Electromagnetic Field Immunity. (Requirement
80MHz - 1GHz @ 10V/m)
BS EN 61000-4-6: 2009 Immunity to conducted disturbances induced by radio frequency fields
(Requirement 150kHz - 80MHz @ 10V/m)
BS EN 61000-4-4: 2012 Electrical Fast Transient/Bursts Immunity (Requirements +/- 1kV).
3.4 Operating Environment
The components installed on the network should be the measurement devices, local controller and
communications links. They should be able to operate under the following environment criteria
given in Table 9.
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Local Controllers
Table 9 Operating Environment for Local Controller
Parameter/Component
Requirement
Comments
Mounting
19” Rack mounted, for substation installation
where appropriate
1 x freestanding 19” rack
cabinet per controller
110v AC
Power supply
48v – 110v DC
Insulation IEC 60255-5 test
between all terminals and earth
2.0 kV rms levels for 1 minute
Insulation IEC 60255-5 test
between independent circuits
2.0 kV rms levels for 1 minute
Insulation IEC 60255-5 test
across
1.0 kV rms levels for 1 minute
normallyProtection
Ingress
open contacts
IP54
Humidity IEC 68-2-3 Operational
test
56 days at 40 °C and 95% RH
Maintenance / chronological
lifetime
Ability to operate without any intervention for
10 years and a lifespan of 40 years
Physical size
Be able to fit a 19 inch rack
-5°C to +35°C Indoors
Operating ambient temperature
Communications protocol
compatibility.
-25°C to +55°C Outdoors
≤ 5% variation
Communicate with supported protocols, this
can be direct communication or by using an
intermediate device. The communications will
run separately from the standard
NMS/SCADA system. For example system
may require systems below or similar:



ENMAC interconnectivity
DNP3 compatibility
IEC 60870-5-103
3.5 Installation, Operation and Maintenance
3.5.1
Installation
The extent of the upgrade from an AVC system to an EAVC scheme will depend on the existing
AVC’s functionality. However it would be safe to assume that the existing cabling and voltage and
current signals from the metering/protection VT and CTs are able to be re-used. While this
document refers to them and uses their resultant signals, these items are physically outside of the
scope of the EAVC solution.
19” Rack Mounted cubicles sited in the substation control room are required to house the EAVC
scheme which should be 2280 (H) x 750 (W) x 720 (D) with a 75mmp plinth supplied without any
front access doors. The cubicles should be protected with a final external coat of semi-gloss paint
in Light Admiralty Grey Ref 697 to BS381C.
The cubicle should be water-proof and have a steel metal hinged rear door, padlockable, and the
door should open within the width of the panel. An internal light (240V ac) should be provided in the
panel, operated by a rear door switch. The panels should be fully vermin-proof, with bottom gland
plates provided for all cable entries.
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Equipment that is mounted inside of the cubicle should not prevent access to terminals or wires at
the rear or at the front of the panel. No equipment should be mounted across the width of the
panel.
The local controller and any associated switches, fuses/links should be located at a height that is
easily operated by the user. They should be mounted not less than 450mm and not more than
1800mm from floor level. All switches, fuses/links, and instruments should be mounted to be clearly
visible in the normal operating position. Access to such apparatus should not require the use of
tools.
For safety security reasons on substation installations, the control relay should sit outside of where
the heavy equipment is installed and a lockable weather-proof steel cabinet with a side hinged door
for the relay board should be provided.
3.5.2
Indicators
The local controller should be capable of displaying the following LED indicators as standard or as
configurable indicators. They can be integral to or discrete from, the user interface with suitable
labelling:
 Voltage above the dead band
 Voltage below the dead band
 Relay voltage above a pre-set level
 Relay voltage below a pre-set level
 Tap freeze applied
 Tap change lockout
For OLTC:
 Excessive circulating current
 3% and 6% voltage reduction and call to unity power factor applied
3.5.3
Alarms
The local controller should be able to initiate the following alarms via a configurable time delay:
 Voltage remaining outside the dead band (over and under voltage).
 Panel Aux. Supply Fail.
 Tapchange Incomplete.
 Tapchange Lockout.
 AVC VT supply fail.
 Inter controller communications fail.
3.5.4
Earthing of Enclosure Cubicles
Earthing of panels should be in line with ENA TS 41-24.
Means should be provided for connecting the 19” EAVC enclosure cubicle to the substation
earthing system. For non-directly connected equipment the minimum cross sectional area of
these connections should be 70mm² copper cable or 25mm x 3mm copper tape. For directlyconnected equipment the earth connection to the main equipment should comply with the
specification for the main equipment.
Where the EAVC enclosure cubicle is installed as part of a suite of cubicles, the earth bar should
extend across the cubicle and should be drilled and provided with a drilled link of the same material
and cross sectional area as the cubicles earth bar, for the connection to adjacent cubicles. The
cubicle design should facilitate this connection. The earth bar and connection link should be so
designed so that any one cubicle can be removed from the suite without compromising the earthing
of other cubicles.
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All connections to the substation earthing system should be bolted. The faces of all bolted
connections should be clean and either tinned or suitably protected against corrosion for the life of
the equipment. The bolted connections should have a resistance which is not more than that of an
equivalent length of bar.
Where earth connections are made to metalwork, the system used should ensure good electrical
contact between the connections and metalwork, whilst maintaining necessary protective and
corrosion resistant finishes.
3.5.4.1
Earthing of Small Apparatus and Equipment
The EAVC enclosure should be provided with a suitable means of connecting equipment and
apparatus to the earth bar of the enclosure.
Protective bonding of equipment housed within the enclosure should be afforded by means of a
direct radial connection from the enclosures bonding terminal or integral earth bar.
The bonding and earthing of all ancillary components within the EAVC enclosure such as doors,
covers supports, gland plates and sub-racks should be continuous and afforded by means of an
insulated wire, of a cross section not less than 2.5mm². Specific means should be provided for
earthing, e.g. the use of assembly bolts is not permitted.
The disconnection of any component within the enclosure should not compromise the integrity of
the bonding to earth of any other equipment in the enclosure.
3.5.5
Maintenance
All equipment should operate for a minimum of 3 years. All equipment should operate without any
intervention or maintenance.
3.6 Training Requirements
3.6.1
OLTC at Primary Substations
There are no extra training requirements for the EAVC scheme as it operates primarily as an
ordinary AVC scheme except that it accepts a variable setpoint and sends its inputs as outputs to
the GUS.
3.6.2
Switched Capacitor Bank
The manufacturer should indicate what training they can provide to ensure that staff are fully
conversant with the installation and maintenance of switched capacitor bank’s local controller and
ancillary equipment.
3.6.3
In-line Regulator
There will not be any need for training of staff in the installation and use of the control equipment
due to their experience of using such control equipment in primary transformer voltage control.
The manufacturer should detail what training ability they have and the likely costs of that training for
any additional functions that may be desirable to have that would be additional to the standard skill
sets.
If the manufacturers have other functions that are, desirable to have, or add to the schemes
usability over and above a standard AVC scheme, they should detail what training ability they have
and the likely costs of that training, to enable staff to be compliant in its use.
3.7 Support and Development Requirements
The EAVC scheme should be integrated into part of an overall smart grid system. Manufacturers
should detail the support services that they offer.
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4. WEEE Regulations
Under the 2002/96/EC directive of the European Parliament and council, for the collection, separation
and treatment of electronic waste, manufacturers must:
 State whether any of their products come under the Waste Electrical and Electronic Equipment
Regulations (WEEE). If not the manufacturer should explain why they are exempt.
 State what provisions they have in place for the collection and recycling of the product at the
end of its useful life.
 State what discounts would be available to switch the responsibility of the products disposal
from the manufacturer to DNOs.
5. References
The products described within this recommendation should comply with all current versions of the
relevant International Standards, British Standard Specifications and all relevant Energy Networks
Association Technical Specifications (ENATS) current at the time of supply.
5.1 External Documentation
Reference
BS EN60529
Title
Degrees of protection provided by Enclosures (IP Code)
BS EN 60255
Measuring relays and protection equipment
ENA TS 50-18 :2013
Application of Ancillary Electrical Equipment
ENA TS 50-19
Standard Numbering for small wiring
ENA TS 41-24
Guidelines for the Design, Installation, testing and maintenance of main
earthing Systems in Substations
High voltage switchgear and controlgear
IEC 62271-1
BS ISO 3864-1:2011
Electromagnetic compatibility (EMC) – Part 4-30: Testing and
measurement techniques – Power Quality measurement methods
Graphical symbols and signs – safety signs, including fire safety signs
BS EN 61000-6-2:2005
Generic standards – Immunity standards for industrial environments.
IEC 61000-4-30
BS EN 60801-2:1993, IEC Electromagnetic compatibility for industrial-process measurement and
60801-2:1991
control equipment. Electrostatic discharge requirements
BS EN 61000-43:2006+A2:2010
BS EN 61000-4-4:2012
Testing and measurement techniques. Radiated, radio-frequency,
electromagnetic field immunity test
Testing and measurement techniques – Electrical fast transient/burst
immunity test
BS EN 61000
Electromagnetic compatibility
BS 2782-5:Method
552A:1999, ISO
4582:1998
Methods of testing plastics — Optical and colour properties, weathering —
Determination of changes in colour and variations in properties after
exposure to daylight under glass, natural weathering or laboratory light
sources
The supplier should provide with the tender full technical details of the equipment offered and should
indicate any divergence from these standards or specifications.
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5.2 Internal Documentation
Reference
Title
(For Northern
Powergrid) see:
NPS/003/001
Other DNO’s
please refer to your Technical Specification for 66kV and 132kV Voltage Transformers
current
specifications for
Transformers
required for your
PCS output step
voltage
(For Northern
Powergrid) see:
NPS/003/023
Other DNO’s
please refer to your Technical Specification for 33, 66 & 132kV Post CT’s
current
specifications for
Transformers
required for your
PCS output step
voltage
(For Northern
Powergrid) see:
NPS/003/021
Other DNO’s
please refer to
your current
specifications for
Transformers
required for your
PCS output step
voltage
Technical Specification for System Transformers CMR (Continuous Maximum
Rated)
(For Northern
Powergrid) see:
NPS/003/012
Other DNO’s
please refer to your Technical Specification for System Transformers CER (Continuous Emergency
Rated)
current
specifications for
Transformers
required for your
PCS output step
voltage
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5.3 Summary of Amendments
Reference
Clause 1
Clause 3.2.6– Table 6
Local controller
Clause
3.2.6– Table 6
Essential
Clause
3.2.6– Table 67
FunctionalityTable
Clause 3.5.1 – 3rd and
6th paragraph
Clause 5.1 and entire
document
Clause 3.3
Title
Update superseded documents table
Addition of locking Policy requirements for operating switches
Addition of tap freeze function while retaining relay power
Addition of voltage take off requirement for LV Board direct reference
Addition of asset security requirements
Update on external documentation references and addition of reference checks
when possible
Addition of operational failure mode in the event of communications failure
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6. Definitions
Term
CLNR
DNO
EHV
GUS
HV
MVA
NMS
SCADA
GPRS
Local control
Remote control
Supervisory
control
Enhanced
Automatic
Voltage Control
(EAVC)
Local controller
Definition
Customer Led Network Revolution
Distribution Network Operator
Extra High Voltage (the 33kV network and above)
High level control system that gathers network information in real time from
distributed monitors, and uses specified algorithms to determine each voltage
control device’s setpoint for the optimum network voltage levels.
High Voltage (network from 6kV to 33kV)
Megavoltamperes (apparent power)
Network management System
Supervisory control and data acquisition
General Packet Radio Services (GPRS) is a packet-based wireless
communication service that provides data rates from 56 up to 114 Kbps and
continuous connection to the Internet for mobile phone and computer users.
GPRS is based on Global System for Mobile (GSM) communication system.
Control at the Primary transformer OLTC
Control at the AVC local controller
Control inputs/outputs from SCADA/Control Room/GUS
An automatic voltage control system that becomes enhanced by its ability to:
Send its monitor inputs as outputs to a high level control system (GUS) Receives
network goals from a high level control system (GUS)
Voltage relay or other suitable device that provides automatic voltage control.
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Appendix 1a – Schedule of Suppliers Technical Data
The following Technical schedules must be completed by suppliers
Essential & Desirable Data Outputs (Table 3 & 4)
Type
Comments
Tap Up/Raise Volts
Tap Down/Lower
Volts
Block
Alarms
Voltage
Current
Estimated
Generation
Supported
Communication
methods
Ability to Accept Expected Inputs from GUS (Table 5)
Input
Comments
Handshake/Heartbeat
Setpoint Check/Change
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Appendix 1b – Schedule of Suppliers Technical Data – Local Controller
Local Controllers Functionality – (Compliance with table 6 and 8)
Function
Comments
Essential Inputs
Description
Function
VT Monitoring
CT Monitoring
Control Outputs
Description
Raise signal
Lower signal
Status Checks
Description
Function


Function
Auxiliary Voltage
Line Voltage
Metering
Tap Lock
Tap Change Master Lock out
feature
Tap position
OLTC/Capacitor Bank operation
Self-supervision signal
Overcurrent Blocking
Overvoltage Blocking
Undervoltage Blocking
Estimated Generation
External Inputs
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Function
Comments
Description
Function
23
Manual Mode
Automatic Mode
Supervisory Mode
Reduce set voltage (-3%, -6% )
Internal Functions
Acceptance of a setpoint over a
communications link
Hold a Default setpoint
Load Drop Compensation
An ability to function in Mode1 and
Mode 2
The ability to detect a
handshake/heartbeat
Runaway Protection
Time Delays
For OLTC - A method of reducing
the amount of circulating current
between paralleled transformers.
For Capacitor Banks – Transient
Free switching.
For Capacitor Banks – Method of
ensuring the capacitors are in
their correct switching pattern.
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Appendix 1c – Schedule of Suppliers Technical Data – EAVC Ancillary
Equipment
Ancillary Equipment Functionality - (Compliance with Table 7)
Parameter/Component
Comments
Static Over voltage Relay
Reset Button
Supervisory/Remote Switch
GUS/Remote Switch
Manual/Automatic Switch
‘Tap Up’/’Raise Volts’ button
‘Tap Down’/’Lower Volts’ button
19” Rack Cabinet
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Appendix 1d – Schedule of Suppliers Technical Data – Compliance with
Specification
Parameter/Component
Comments
Mounting
Power supply
Insulation IEC 60255-5 test
between all terminals and earth
Insulation IEC 60255-5 test
between independent circuits
Insulation IEC 60255-5 test
across normally open contacts
Ingress Protection – Clause
3.1.1.2 & 3.1.1.3
Humidity IEC 68-2-3 Operational
test
Maintenance / chronological
lifetime
Physical size – Clause 3.5.1
Operating ambient temperature
Communications protocol
compatibility. Clause 3.3
Small wiring and terminal blocks clause 3.1.1.5
Marking & Labelling – clause
3.1.1.4
Indicators - clause 3.5.2
Alarms - clause 3.5.3
Earthing of enclosures – clause
3.5.4
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Appendix 2a – Self Certification Conformance Declaration – Tables 1-9 of this specification
Supplier/Product Technical Compliance Grid (to be completed by the supplier for each variant offered).
The EAVC’s shall comply with the latest issues of the IEC’s and British Standards quoted within this specification.
Key elements from the above standards and this specification have been quoted to amplify and/or clarify the requirements of those Standards. This check
sheet identifies the particular clauses of the aforementioned Standards relevant to EAVC’s.
The manufacturer shall declare conformance or otherwise, clause by clause, using the following levels of conformance declaration codes for each conductor.
Instructions for completion
N Conformance declaration codes
 When Cs1 code is entered no remark is necessary
o N/A = Clause is not applicable/ appropriate to the product
t Cs1 = The product conforms fully with the requirements of this clause
e Cs2 = The product conforms partially with the requirements of this clause
 When any other code is entered the reason for non-conformance
S Cs3 = The product does not conform to the requirements of this clause
shall be entered
e Cs4 = The product does not currently conform to the requirements of this clause,
p but the manufacturer proposes to modify and test the product in order to conform.
 Prefix each remark with the relevant ‘BS EN’ or ‘ENATS’
a
r
ate Self Certification Conformance Declaration sheets shall be completed for each product being offered.
Manufacturer:
Product Reference:
Name:
Signature:
Date:
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Specific requirements within this specification
Clause/Sub Requirements
-clause
Conformanc
e Code
Table 1
Compliance with Essential Inputs
Table 3
Compliance with Essential Outputs
Table 4
Compliance with Essential Data Outputs
Table 5
Compliance with Expected Inputs from GUS
Table 6
Compliance with Essential Functionality of the local
controller.
Table 7
Compliance with Essential Functionality of the EAVC
Ancillary Equipment.
Table 9
Compliance with the Operating environment
requirements for the Local Controller
Remarks
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Appendix 2b – Self Certification Conformance Declaration
The EAVC’s shall comply with the latest issues of the relevant International and British Standards. ENATS 50-18 is intended to amplify and or clarify the
requirements of those standards
This check sheet identifies the particular clauses of the aforementioned Standards relevant to EAVC’s.
The manufacturer shall declare conformance or otherwise, clause by clause, using the following levels of conformance declaration codes for each conductor.
Instructions for completion
N Conformance declaration codes
 When Cs1 code is entered no remark is necessary
o N/A = Clause is not applicable/ appropriate to the product
t Cs1 = The product conforms fully with the requirements of this clause
e Cs2 = The product conforms partially with the requirements of this clause
 When any other code is entered the reason for non-conformance
S Cs3 = The product does not conform to the requirements of this clause
shall be entered
e Cs4 = The product does not currently conform to the requirements of this clause,
p but the manufacturer proposes to modify and test the product in order to conform.
 Prefix each remark with the relevant ‘BS EN’ or ‘ENATS’
a
r
ate Self Certification Conformance Declaration sheets shall be completed for each product being offered.
Manufacturer:
Product Reference:
Name:
Signature:
Date:
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IEC
ENATS 50-18
Clause / Sub
clause
IEC
IEC622
62271-1
71-200
2
2
Requirement
Service conditions
Confor
mance
code
ENATS 50-18
Clause / Sub Requirement
clause
2
3.2
3.3
3.4
Table 3.1
5.4
5.4
5.4.1
5.4.4.1
5.4.4.2
5.4.1.3
5.4.1.3
5.4.1.3
5.3
5.4.3
5.10
5.4.4.5.1
5.4.4.5.2
29
5.3
4.1
4.1
4.1
4.1
4.2
4.2.1
4.2.1
4.2.2
4.2.3
4.3
4.4
4.6.2
4.7
4.8
5.1
5.2
5.2.1
Confor
mance
code
Service conditions
Electromagnetic compatibility
Type Tests (see separate conformance
declaration)
Voltage
and frequency limits
Correct operation at DC Voltage Limits at
Apparatus Terminals
General
Materials - non-ignitable
Materials – Dimensionally stable
Dust protected contacts and mechanisms
Minimum height of terminal block
arrangements (100mm)
Provision of padlocking on doors
Selection of components
Installation of components
Access to apparatus and components
Max/Min heights of components
Degree of protection
Padlocking
Earthing of enclosures
Earthing of small apparatus and equipment
Access to connection interface Terminals and
Apparatus
Fire Hazard
Marking and labelling
Small wiring
Connections
Terminals and terminations
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IEC
Clause
clause
IEC
62271-1
30
ENATS 50-18
/
Sub
IEC622
71-200
Requirement
Confor
mance
code
ENATS 50-18
Clause/ Sub Requirement
clause
5.2.2
5.2.3
5.2.4
5.3
6.1
6.4
6.5
7
7.2.1
7.2.2
7.3
8.1
8.2
8.3
8.4
8.5
Confor
mance
code
Terminal Blocks
Termination clamps
Insulation displacement connectors
Plug and socket connectors
Fuses and links
Miniature circuit breakers
Supply isolation
Control and selector switches
Classification
Rating
Design
Instruments
Electrical measurement transducers
Control and interposing relays
Small contactors
Indicating lamps and fittings
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Appendix 2c – ENA TS 50-18 Type test Self Certification
Conformance Declaration
Instructions for completion
 When Cs1 code is entered no remark is necessary
Manufacturer:
Product Reference:
Name:
 When any other code is entered the reason for non-conformance
shall be entered
Signature:
1.
Test requirement
Emission standards from
the auxiliary and control
1 standards.
Immunity Tests on
auxiliary and control
circuits
2
2.
Specifications and
standards
 Prefix each remark with the relevant ‘BS EN’ or ‘ENATS’
Date:
3.
Rated
Value
4.
Test
req’d
(Y/N)
IEC 62271-1 clause 6.9.1.2
Y
Electrical fast
transient/burst test
IEC 62271-1 clause 6.9.2.3
Y
Oscillatory wave immunity
test
IEC 62271-1 clause 6.9.2.4
Y
5.
6.
Confor Test
mance Value
7.
Date of
test
8.
Test
Station
Report/
Cert No.
Copyright Northern Powergrid (Northeast) Limited, Northern Powergrid (Yorkshire) Plc, 2014
9.
Witness
I,M or
ENA**
10.
Remarks
Document Reference:
Version: 1.0
Test requirement
CLNR-L209
Date of Issue: December 2014
Specifications and
standards
Rated
Value
32
Test
req’d
(Y/N)
Confor Test
mance Value
Date of
test
Test
Station
Report/
Cert No.
3 Additional EMC test on
auxiliary and control
circuits
Ripple on d.c. input power
port immunity test
IEC 62271-1 Clause
6.9.3.2
Y
Voltage dips, short
interruptions and voltage
variations on d.c. input
power port immunity tests
IEC 62271-1 Clause
6.9.3.3
Y
Functional tests
IEC 62271-1 Clause 6.10.2
Y
Electrical continuity of
earthed metallic parts test
IEC 62271-1 Clause 6.10.3
Y
Auxiliary contact rated
Continuous current
IEC 62271-1 Clause
6.10.4.2
Y
Auxiliary contact
rated Short time
withstand current
IEC 62271-1 Clause
6.10.4.3
Y
Auxiliary contact rated
Breaking capacity
IEC 62271-1 Clause
6.10.4.4
Y
4 Additional EMC test on
auxiliary and control
circuits
Verification of the
operational
characteristics of
auxiliary
contacts:
Copyright Northern Powergrid (Northeast) Limited, Northern Powergrid (Yorkshire) Plc, 2014
Witness
I,M or
ENA**
Remarks
Document Reference:
Version: 1.0
Test requirement
CLNR-L209
Date of Issue: December 2014
Specifications and
standards
Rated
Value
33
Test
req’d
(Y/N)
5
Confor Test
mance Value
Date of Test
test
Station
Report/
Cert No.
Environmental Tests
Cold test
IEC 6.2271-1 clause
6.10.5.2
Y
Dry Heat test (Outdoor) IEC 6.2271-1 clause
6.10.5.3
Y
Damp heat test, steady
IEC 6.2271-1 clause
6.10.5.4
Y
IEC 6.2271-1 clause
6.10.5.5
Y
Vibration response and IEC 6.2271-1 clause
seismic tests
6.10.5.6
Y
IEC 6.2271-1 clause
Y
state test (Outdoor)
Cyclic humidity test
Final condition check
6.10.5.7
6
Dielectric Test
IEC 6.2271-1 clause 6.10.6
Y
Communications GPRS Electromagnetic Compatibility Tests for the communication equipment
7
Emission standards
for residential,
commercial and
light industrial
environments.
BS EN 61000-6-3:2007
Y
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Witness
Remarks
I,M
or
ENA**
Document Reference:
Version: 1.0
Test requirement
8
9
10
11
12
Immunity Standards
–Immunity for
industrial
environments
EMC for industrialprocess
measurement and
control equipment –
Electrostatic
discharge
requirements
EMC
– Radiated,
radio- frequency,
electromagnetic
Min values
Air test
–
field
immunity
4kV Contacts – 8kV
EMC – Electrical
fast transient/burst
Min Values
immunity
test
27Mhz – 1Ghz @
EMC
10V/m- Immunity to
Min
values
conducted
80Mhz
– 1Ghz @
disturbances
+/1kV
10V/m
induced by radio
frequency fields
CLNR-L209
Date of Issue: December 2014
Specifications and
standards
Rated
Value
BS EN 61000-6-2:2005
Y
BS EN 60801-2:1993
Y
BS EN 61000-4-3:2002
Y
IEC 61000-4-4:2012
Y
BS EN 61000-4-6:2007
Y
Test
req’d
34
Confor Test
mance Value
(
Y
/
N
)
Date of Test
test
Station
Report/
Cert No.
Witness
I,M or
ENA**
Min Values 150khz
– 80Mhz @ 10V/m
Copyright Northern Powergrid (Northeast) Limited, Northern Powergrid (Yorkshire) Plc, 2014
Remarks
Document Reference:
CLNR-L209
Version: 1.0
Date of Issue: December 2014
35
*Conformance declaration codes
Ct1 = Independent witnessed tests
Ct2 = Not fully independent witnessed tests
Ct3 = Self verified tests
Ct4 = Alternative tests / evidence offered
Ct5 = Manufacturer has underwritten that the product meets the functional and performance requirements without further testing
Ct6 = Not tested
Copyright Northern Powergrid (Northeast) Limited, Northern Powergrid (Yorkshire) Plc, 2014
Document Reference:
Version: 1.0
CLNR-L209
Date of Issue: December 2014
36
Appendix 3 – Addendum to Supplier Requirements
Please indicate Packaging/delivery information
Details of how this product will be packaged and delivered shall be provided.
Project specific requirements
Any project specific requirements will be provided for inclusion in this appendix.
Copyright Northern Powergrid (Northeast) Limited, Northern Powergrid (Yorkshire) Plc, 2014
Document Reference:
Version: 1.0
CLNR-L209
Date of Issue: December 2014
37
Appendix 4 – Pre-commission testing, Routine Inspection and Maintenance
requirements
Suppliers shall provide details of any recommended pre-commission testing or installation requirements.
Additionally suppliers shall also provide information regarding any periodic inspection or maintenance
requirements to be undertaken during the lifetime of their product.
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Document Reference:
Version: 1.0
CLNR-L209
Date of Issue: December 2014
38
Appendix 5 – Technical Information Check List
The following information shall be provided by the supplier for technical review. Additional information shall be
provided if requested.
Requirement
Provided
(Y/N)
Appendix 1 – Completed technical schedules
Appendix 2 – Completed self-certification conformance declaration
Appendix 3 – Packaging and delivery information
Appendix 4 – Inspection and testing recommendations
Type test evidence
Routine test plan (example)
Copyright Northern Powergrid (Northeast) Limited, Northern Powergrid (Yorkshire) Plc, 2014
Document Reference:
Version: 1.0
CLNR-L209
Date of Issue: December 2014
39
Appendix 6 – Schedule of Components
Item
Description
1
2
3
4
5
6
7
8
9
10
11
12
Local Controller
19” Rack Cabinet
Communications Link
Manual/Auto Switch
Supervisory/Remote Switch
GUS/Remote switch
‘Tap Up’/’Raise Volts’ button
‘Tap Down’/’Lower Volts’ button
Test Block
Static Over Voltage Relay
Reset Button
Fuses
Price
Copyright Northern Powergrid (Northeast) Limited, Northern Powergrid (Yorkshire) Plc, 2014