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DATB Specifications

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Detailed Specifications

Distribution Automation Test Bed (DATB)

“This Tender Document shall be used only for

the purpose of responding to this tender and

cannot be used for any other purpose without

written consent from CPRI.”

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Contents 1 Introduction .......................................................................................................................................... 5

2 Abbreviations ........................................................................................................................................ 5

3 Intended uses for the DATB .................................................................................................................. 6

3.1 Exercise the DATB Use Cases ........................................................................................................ 6

3.2 Demonstrate and Verify Distribution Automation functions ....................................................... 6

3.3 Interoperability Testing ................................................................................................................. 7

3.3.1 CIM Compliance of DA Controls per IEC 61968 .................................................................... 7

3.4 Parts of the Distribution Automation Test Bed ............................................................................ 8

3.4.1 A Generic Integration Model ................................................................................................ 8

3.4.2 Small scale transient simulation ........................................................................................... 8

3.4.3 Larger scale distribution simulation ...................................................................................... 8

3.4.4 Integration with the SituTB SCADA/ADMS system ............................................................... 8

3.4.5 Integration with the 11kV transformer pad .......................................................................... 8

3.4.6 Integration with the substations ........................................................................................... 8

3.4.7 Analysis tools ......................................................................................................................... 8

4 DATB Components ................................................................................................................................ 9

4.1 General Requirements for Substation Equipment ........................................................................ 9

4.2 Small Scale Simulation ................................................................................................................ 11

4.2.1 Small Scale Simulator specification: .................................................................................... 11

4.2.2 Interface from Simulator to SCADA/ADMS ......................................................................... 11

4.3 Large Scale Simulation ................................................................................................................ 12

4.3.1 Required for Large Scale Simulation ................................................................................... 12

4.3.2 Integration with SituTB SCADA/ADMS ................................................................................ 12

4.4 Integration with SGTB 11kV transformer pad physical switchgear ............................................ 13

4.4.1 Recommended 11kV equipment for the Transformer Pad (11kV Line Hardware) (supply of

these items are not in the scope of this tender; however information is provided for ease of

integration with these devices; the selected bidder shall support for integration with these items;

these items will be procured through separate tender or CPRI will arrange these items) ................. 13

4.5 Generic Integration Model .......................................................................................................... 15

4.5.1 Uninterruptible Power Supply ............................................................................................ 16

4.6 Analysis tools............................................................................................................................... 16

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4.6.1 SCADA Simulator ................................................................................................................. 16

4.6.2 Station Level Computer....................................................................................................... 17

4.6.3 Gateway .............................................................................................................................. 17

4.6.4 Time Reference (supply scope covered under Situational Awareness test bed part of this

tender) 18

4.6.5 Power Supply ...................................................................................................................... 18

4.6.6 LAN Ethernet Switch ........................................................................................................... 18

4.6.7 Portable Notebook Computers (2 recommended): ............................................................ 19

4.6.8 Router ................................................................................................................................. 19

4.7 Miscellaneous and Spare Parts ................................................................................................... 20

5 RTU Specification ................................................................................................................................ 20

5.1.1 Data Acquisition .................................................................................................................. 20

5.1.2 Estimating RTU Point Count ................................................................................................ 23

5.1.3 RTU Architecture ................................................................................................................. 23

5.1.4 Power Supply ...................................................................................................................... 26

5.1.5 Local Control Panel ............................................................................................................. 27

5.1.6 RTU Software ...................................................................................................................... 28

5.1.7 Enclosures ........................................................................................................................... 29

6 Physical Structure (Rack)r ................................................................................................................... 30

7 Communication Network .................................................................................................................... 31

7.1 Network Performance Requirements ......................................................................................... 31

7.2 Connection from DATB to the SGTB external transformer pad .................................................. 31

7.2.1 Fiber Link Specification ....................................................................................................... 32

7.3 SNMP Manager ........................................................................................................................... 32

7.4 Redundancy Requirements ......................................................................................................... 32

7.5 Cyber Security Requirements for Distribution Automation ....................................................... 32

8 Reliability and Availability vs. Flexibility .............................................................................................. 33

9 Contracting Options ............................................................................................................................ 33

10 Feature Quantities: ............................................................................................................................. 34

11 Mapping Functions to Features (only for information) ....................................................................... 34

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Figures Figure 3-1 Interoperability Context-Setting Framework, aka GWAC Stack .................................................. 7

Figure 4-1: DATB Components .................................................................................................................... 10

Figure 4-2 11kV Equipment on SGTB Transformer Pad ............................................................................. 14

Figure 4-3 Communications using VPN across the SituTB, DATB, and SASTB over the CPRI network and

cellular connections. ................................................................................................................................... 16

Figure 6-1 Rack mounts for DATB Equipment ............................................................................................ 31

Tables

Table 2-1 Abbreviations ................................................................................................................................ 6

Table 10-1 DATB Features List .................................................................................................................... 34

Table 11-1 Selection options for each Feature ........................................................................................... 34

Table 11-2 Function dependency on Features ........................................................................................... 35

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1 Introduction The Distribution Automation Test Bed (DATB) consists of all equipment, devices, and software

associated with information flow within the test bed. In this respect, the DATB includes

Small scale transient simulation of a section of the power grid using one or more Relay Test Sets

for the simulation of distribution faults and automation actions.

Integration with the CPRI Power Systems Laboratory RTDS and Opal-RT simulators for larger and

more complex simulations

Integration with the Situational Awareness Test Bed SCADA/ADMS system.

Integration of distribution hardware installed on the SGTB transformer pad for visual

demonstration of automated and remote control of feeder switchgear.

Instrumentation used to test and verify conformance of DA devices to relevant standards.

Devices and fixtures needed to realize the integration of DATB with physical signals, including

o Networking equipment

o Remote Terminal Units

o Smart power meters

o Intelligent field device controls such as recloser, load break switch, and Communicating

Fault Passing Indicator interface controls.

This document provides the DATB specification. Conceptual Logical and Physical architectures of the

Distribution Automation System are suggested.

2 Abbreviations

Term Meaning

CCTB Communications and Computing Test Bed

DATB Distribution Automation Test Bed

DERTB Distributed Energy Resources Test Bed

EVTB Garage of the Future Test Bed

HANTB Home Area Network Test Bed

HSR High-availability Seamless Redundancy (IEC 62439-3 clause 5)

MOAB Motor operated air breaker

PRP Parallel Redundancy Protocol (IEC 62439-3 clause 4)

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Term Meaning

PSTB Power System Test Bed

SASTB Substation Automation System Test Bed

SituTB Situational Awareness Test Bed

SNMP Simple Network Maintenance Protocol

SNTP Simple Network Time Protocol

Table 2-1 Abbreviations

3 Intended uses for the DATB

3.1 Exercise the DATB Use Cases

Per the Conceptual Design Report (SGTB Task 5) the DATB will support the following use cases:

6 - Distribution Automation Test Bed Use Cases

6.1 FLISR & FDI

6.2 Volt-VAR Control

6.3 Reconfiguration of the circuit on overloading scenario.

6.4 Load shedding

6.5 CIM compliance for DMS as per IEC 61968

Demo field device operation on the SGTB Transformer Pad

Observe 220kV and 33kV substation operation

3.2 Demonstrate and Verify Distribution Automation functions

The DATB will be used to stage simulated interconnecting distribution feeders to observe grid behaviour

under load, fault and overload conditions. An overlay of RTU and physical distribution automation

controls will interact with the simulations, allowing the analysis of the effectiveness of the automation

scheme, the expected time span required for operation and reduction of outage time due to DA

operation, improvement in Key Performance Indicators (SAIDI, SAIFI, CAIDI, etc. computed by the SituTB

SCADA/ADMS), and the quality of the information available to distribution system operators and field

service technicians. SGTB will demonstrate the remote operation of field devices by operating the

switchgear installed on the SGTB transformer pad just outside the building.

DATB will install Router, RTU, and selected equipment in the 33kV on campus and 220kV off campus

substations for observation of the operation of the real power grid.

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Demonstration of these techniques will be of value to CPRI associates interested in employing the

methods on their own distribution grids, and in educational opportunities for utility and academic

associates.

3.3 Interoperability Testing

In addition to conformance testing of the above standards, DATB will be used to verify Interoperability

of multiple vendor devices within the DATB. Interoperability is categorized by the GridWise Architecture

Council Interoperability Context Stack (GWAC Stack). The GWAC Stack separates interoperability issues

into basic contexts:

Figure 3-1 Interoperability Context-Setting Framework, aka GWAC Stack

The lower four layers of the GWAC Stack map well to laboratory testing procedures:

Basic connectivity deals with connector type, media type, electrical parameters, etc.

Network IOP addresses the ability of signals to move correctly through the IT network.

Syntactic IOP deals with syntax used to form messages and message parts.

Semantic Understanding addresses the ability of different devices to make good use of the

shared information. CIM is intended to simplify the semantic understanding between active

devices in the distribution system.

3.3.1 CIM Compliance of DA Controls per IEC 61968

IEC 61968 specifies the Common Information Model (CIM) for distribution applications. This set of

coordinated standards defines architecture, records management, information format for exchange

between devices and systems applied to the utility distribution system, and other details related to the

consistent treatment of information to ease integration and interoperability. Hardware and software are

specified allowing SGTB technicians to observe and log these information flows for IEC 61968

compliance determination.

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Interoperability Testing requires the staging of devices, systems, and software from different vendors

and verifying that these devices interoperate in reliable and predictable ways. The DATB will provide the

structures and fixtures to facilitate this type of testing.

3.4 Parts of the Distribution Automation Test Bed

The DATB consists of the following parts:

3.4.1 A Generic Integration Model

Used for integrating CPRI facilities and laboratories into the DATB.

3.4.2 Small scale transient simulation

Simulation of interconnected distribution feeders interfaced to the Situational Awareness Test Bed

SCADA/ADMS system. This small scale simulator is realized by a relay test set with sufficient analog

outputs and digital simulation of up to 20 distribution buses with feeder loads, front-ended with the

Generic Integration Model.

3.4.3 Larger scale distribution simulation

Simulation of more complex distribution feeder configurations. This larger scale simulation is realized by

integration of the DATB and SituTB with the existing CPRI Power Systems Lab RTDS and Opal-RT

simulators, physical distribution field controls, Hardware in Loop testing, using the Generic Integration

Model and the CPRI IP network.

3.4.4 Integration with the SituTB SCADA/ADMS system

Integration with SituTB using the CPRI network and the Generic Integration Model Router and RTU.

3.4.5 Integration with the 11kV transformer pad

Integration with physical switchgear devices located on the SGTB building transformer pad for

demonstration and verification of the operation of field devices by automated control and distribution

operator command, using a 12-strand fiber optic network link, GIM Router/VPN, RTU, and other field

controls.

3.4.6 Integration with the substations

Integrate the remote 220kV substation using the router cell modem and the local 33kV substation using

the router on the CPRI campus network. Modernization hardware in both substations is assumed from

another project.

3.4.7 Analysis tools

Hardware and software ools for the capture and analysis of information flows throughout the DATB

between field components, field to station, and field to distribution control center.

DATB will interact with the Situational Awareness Test Bed (SituTB), the Substation Automation Test Bed

(SASTB), and the CPRI Power Systems Lab for evaluation of automation system performance in selected

testing scenarios. Other on and off campus locations may be added using the Generic Integration Model.

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4 DATB Components DATB shall be configured as indicated in figure 4-1. Integration of the several components of the DATB

shall be based on the existing CPRI backbone TCP/IP network with VPN-enabled Routers and RTUs.

4.1 General Requirements for Substation Equipment

Station Level IEDs shall provide at least (2) Ethernet ports for redundant connection to the Dual Station

LAN and for support of PRP and HSR.

Station Level IEDs shall support IEC 61850 and other international standards, particularly:

61850-3 General requirements (electrical and environmental stresses)

61850-8-1 Publish and subscribe to GOOSE messaging by Ethernet Multicast

61850-9-2 Subscribe to Sampled Value Streaming by Ethernet Multicast

61850-9-3 Time synch per IEEE-1588

61850-90-1 Inter-substation GOOSE messaging publication and subscription

61850-90-2 Station to control center GOOSE messaging publication and subscription

61850-90-5 Routing of GOOSE messages, SV streams, and synchrophasor streams outside of

the Local Area Network

62351 Support for Device Level Security including user authentication, multiple user

roles, user role based functional authorization, and protected firmware revision

62439-3 support for HSR network loops and PRP on dual station and process LAN

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Figure 4-1: DATB Components

DATB

Generic Integration Model to Power System Lab

Transformer Pad using fiber link

SituTB

Small Scale Simulation

Small SCADA/ADMS Display (2x2)

SCADA/ADMS

Display Control

OperatorOperator

Large Scale Simulation

IED

FPI

Recloser

RMU

LBS

RTU

CPRI Campus Network

Analysis ToolsAnalysis Tools

Routerw/Gateway

VPNIEC-104

RouterVPN

RouterVPN

RouterVPN

Fiber LinkIEC-104

Wireless Link

RTU IEC-104

IED

RTUIEC-104

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4.2 Small Scale Simulation

Small Scale Simulation components shall be under complete control of the DATB staff. The simulator

shall execute on Relay Test Set hardware with transient simulation capability.

Distribution control equipment can be exercised using Relay Test Sets. The addition of simulation

software to the test set permits more complex circuit interactions to be analysed. For example, an

ADMS FLISR test would start with a simulation model of a circuit with protection circuit breaker and

remotely controllable feeder switchgear. With switchgear controllers in the simulation loop, ADMS can

issue commands through a SCADA IEC 60870-5-104 interface to locate the fault, isolate the faulted

section, and restore service to the maximum number of customers.

Signal Generation requirements depend on the extent of excitation of the controls required for the

desired set of tests. (6) current and (4) voltage analog outputs can excite IEDs, metering, and field

control devices such as Recloser, Load Break Switch, and Voltage Regulator controls. Additional

synchronized analog or sampled value (merging units modelled in a simulator and injected into an IED

through a local area Ethernet network) can expose more complex interactions.

4.2.1 Small Scale Simulator specification:

Signal Generator Programmable by connected Windows laptop computer

Hardware In Loop capability

COMTRADE playback

Test scripting

Time synchronization per 61850-9-3 (IEEE 1588 PTP)

(6) current channels with 32 amp capacity, error <1%

(4) voltage channels with 300 VAC phase-ground, error<1%

(10) digital input

(4) digital output relay 300 VAC 8 amp

(4) open collector transistorized output

(10) analog input 300 VAC, minimum sample rate 80 samples/cycle, overload protection

Transient triggering at configured threshold voltage

Programmable simulation of 20 or more buses

o Simulation of 50 or 60 Hz power system signals

o Simulation of (3) 4-channel voltage and 4-channel current Merging Units to Ethernet per

61850-90-2LE Sampled Values

o Sampled Value streams on (2) Ethernet ports to dual Process Bus LAN

o Generation of (>=32) 61850 GOOSE event messages from simulation

o Subscription to (>=32) 61850 GOOSE messages from Device Under Test

4.2.2 Interface from Simulator to SCADA/ADMS

Simulator output shall be fed to different electronic devices, which in turn will be interfaced to the

SCADA/ADMS system in the SituTB using IEC 60870-5-104 (or IEC-104) protocol. Distribution system

conditions read by SCADA polls are available to ADMS; ADMS functions issue commands that are passed

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through SCADA to the distribution automation equipment; the DA equipment feed into the simulator to

alter the simulation results.

Interface devices include

IEC-104 RTU per the section 5 RTU specification

IEC-104 Power meter or IED that can be polled directly by SCADA

IEC-103 Power meters and IEDs with a -104 to -103 Gateway

61850 IEDs per SASTB specification with IEC-104 to 61850 Gateway

IEC 60870-5 Field Controllers for DA hardware with Gateway as needed

This minimum configuration will allow the transient simulation of simpler distribution feeder

configurations with smart field control hardware elements in the control loop of the simulator. The

exercise of the Distribution Automation equipment coupled with protocol analysis tools will allow the

capture and analysis of information exchanges, enabling the technician to evaluate conformance of the

device under test to standards, including IEC-104 SCADA protocol and IEC 61968 information modelling.

4.3 Large Scale Simulation CPRI has an on-campus Power Systems Laboratory with extended simulation capability. An existing mid-

scale RTDS system, and a new large-scale Opal-RT system, are not under full control of SGTB staff, but

are available for SGTB use on a scheduled basis. However, the Power System Laboratory is in another

building on the CPRI Bangalore campus.

CPRI has an existing high-speed IP network that extends throughout the campus. This network will be

used for the IEC 60870-5-104 SCADA operation. By locating SCADA-compatible hardware in a Hardware-

in-the-Loop (HIL) configuration on the Power System Laboratory simulators, SCADA/ADMS is able to

reach out to the Power System Lab to remotely execute ADMS operations.

Access to the Power Systems Lab over the CPRI network shall be through the application of the GIM

Routers configured to create a Virtual Private Network (VPN) between the SituTB and the Power

Systems Lab. The smart digital controls used in DA testing in the Small Scale Simulation may be moved

to the Power System Lab and connected to SCADA/ADMS by VPN over the campus network.

4.3.1 Required for Large Scale Simulation

Power System Lab simulators must have distribution equipment modeling capabilities. If not

existing already, buy those components from the simulator supplier (RTDS or Opal-RT).

CPRI backbone IP network for communication from SGTB to Power Systems Lab.

Generic Integration Model Router and

60870-5-104 SCADA compatible field devices as specified in section 4.1.2.

4.3.2 Integration with SituTB SCADA/ADMS

SituTB SCADA system will employ IEC 60870-5-104 SCADA protocol. This protocol is compatible with

network communication and will be connected to the CPRI campus IP network. Locating IEC-60870-5-

104 compatible devices at the Power Systems Lab will allow SCADA to poll a simulation of distribution

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circuits to enable ADMS functions such as FLISR and Volt-VAR Control. Integration with the IEC 60870-5-

104 SCADA system may require the use of a Gateway device as an intermediary between -104 and the

IED protocol (IEC 60870-5-103 or IEC 61850).

On occasion the interface will support Distributed Energy Resources modelled on the simulator. In such

cases, the Gateway will support the transition from IEC 60870-5-104 to the protocol supported by the

DER device.

4.4 Integration with SGTB 11kV transformer pad physical switchgear

11kV switchgear located outside the SGTB building on the SGTB building power transformer pad will be

accessed by installing an RTU on the pad. Additional equipment such as power meter, power quality

meter, revenue meter, and 61850 merging unit may also be located in that enclosure and interfaced to

potential and current transformers on the low voltage side of the pad mount transformer to observe

building load. The transformer pad equipment shall be mounted in a weather tight enclosure of

sufficient size to avoid crowding or overheating of the equipment, with power and control signal cabling

to the pad switchgear, and twelve-strand fiber optic network cabling back to the SGTB building DATB

space (see section 6.2). The transformer pad RTU is as specified in section 5 below.

4.4.1 Recommended 11kV equipment for the Transformer Pad (11kV Line Hardware) (supply of

these items are not in the scope of this tender; however information is provided for ease of

integration with these devices; the selected bidder shall support for integration with these

items; these items will be procured through separate tender or CPRI will arrange these items)

CPRI desires the installation of 11kV switchgear on the transformer pad just outside the SituTB space.

This equipment shall be positioned such that the status indications of the devices are visible from the

South West window of the SituTB area (room 13), and shall be cabled into the SCADA/ADMS system so

that the switchgear can be operated both by operator command and on certain ADMS functions (e.g.

opening a physical device in the process of managing a simulated distribution automation operation).

The equipment is to include (see Figure 4.2)

(9) 11kV overhead mounted Wireless Communicating Fault Passing Indicators

(1) 11kV pole mounter overhead 3-phase Recloser and auto-reclose controller

(1) 11kV 3-position 3-phase Compact Ring Main Unit with internal RTU and power meters

(1) 11kV Sectionalizer realized as a 3-phase Load Break Switch with LBS controller

(5) 11kV overhead distribution poles with crossarms, brackets, insulators, riser cabling,

overhead conductors, and all required hardware to mount the above equipment.

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Figure 4-2 11kV Equipment on SGTB Transformer Pad

4.4.1.1 Wireless Communicating Fault Passing Indicator

The Fault Passing Indicator (FPI) is used in MV distribution circuits as an inexpensive indicator that fault

current has been observed on the circuit. These are often located at single-phase taps from a 3-phase

overhead circuit, helping line crews to trace the direction to the fault. The DATB will host a total of nine

(9) FPI, located at three locations on the 3-phase overhead conductors. Since little or no current will flow

in the overhead conductors, the FPIs must have rechargeable battery powered supplies.

4.4.1.2 AutoRecloser

An AutoRecloser is a fault-interrupting device installed on 3-phase circuits, configured to open the

circuit if fault current is observed, followed by configurable attempts to reclose the circuit. The recloser

has a controller located nearby that monitors voltage and current on the feeder and determines, based

on protection settings, when to open and reclose the circuit. Reclosers can be manually operated locally

by a lineman or remotely by SCADA/ADMS for reasons other than fault current (e.g. circuit

reconfiguration).

11kV Power Transformer

Compact RMU

LBSRecloser3 FPI 3 FPI 3 FPI

Recloser Control

LBS Control

Enclosure

NetworkSwitch

RTUGateway

MUFPI Receiver

3-Phase 11kV Test Circuit

3-Phase 11kV ServiceSGTB Building

3-Phase 440V Service

12 strand fiber

IEC 61850

Fiber Termination

SituTB

SASTB

DATB

CCTB

Compact RMU

Distrib

utio

n P

ole

Distrib

utio

n P

ole

Distrib

utio

n P

ole

Distrib

utio

n P

ole

Distrib

utio

n P

ole

Fiber Termination

IEC 60870-5-104

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4.4.1.3 Ring Main Unit

A Ring Main Unit (RMU) is a switching device that allows the utility to remotely or locally connect and

disconnect multiple circuits from a small section of bus. The RMU can act as a tap point for a distribution

transformer, a sectionalizing switch, or a distribution automation element for reconfiguring a circuit.

An automated (motor driven with remote control) 3-position Ring Main Unit (RMU) shall be located on

the transformer pad such that a viewer from the SGTB building can see the front panel indications of

switch state when the cabinet doors are open. The RMU positions shall be individually observable and

controllable by commands issued through the SituTB SCADA/ADMS system.

4.4.1.4 Sectionalizer

A Sectionalizer is a switching element that allows a circuit to be opened, isolating the downstream

section of the circuit from the upstream section. Sectionalizing may be accomplished with a load break

switch (LBS) when normal load current is flowing, or may only be able to operate on a de-energized

circuit with no current flow at the time of opening. Sectionalizers often include automation to open the

switch in case of a loss of voltage due to the opening of an upstream circuit breaker, thus isolating any

downstream fault an allowing the circuit breaker to be closed.

The Sectionalizer to be installed on the SGTB Transformer Pad shall include a communication controller

allowing local or remote operation by SCADA/ADMS, and shall automatically open upon a loss of voltage

resulting from operation of the upstream Recloser or RMU.

4.5 Generic Integration Model

CPRI is home to a large number of test laboratories dedicated to specialization in particular areas of

power system engineering. The Generic Integration Model (GIM) is a model for a simple, repeatable

interface from DATB and SituTB on the campus network to other labs around the campus. The Generic

Integration Model uses the campus network for communications when available, placing integrating

components at remote locations for short or long term observation and/or control of other test

environments. Communication shall be established over a Virtual Private Network (VPN), isolating the

DATB device communications from the rest of the CPRI network. Where the campus network is not

readily available, an integral cellular modem I the Router can be used to establish the VPN. Modification

to the CPRI DMZ by CPRI IT personnel will be required to allow this temporary VPN connection from

devices using the cellular connection (see figure 4.3).

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Figure 4-3 Communications using VPN across the SituTB, DATB, and SASTB over the CPRI network and cellular connections.

The Generic Integration Model locates a set of integration hardware at the remote location, connected

to the SituTB/DATB with a VPN. A small RTU provides the most basic input and output needed to

integrate the remote site with SituTB/DATB for observation and control. More sophisticated interface

may be enabled by application of additional IED hardware.

4.5.1 Uninterruptible Power Supply

The GIM shall include an uninterruptible power supply (UPS – see section 4.6.5.1) able to operate the

GIM for a minimum of 1 hour after loss of grid power, and a 19” 45U rack for the mounting of GIM

devices (see section 6).

4.6 Analysis tools

4.6.1 SCADA Simulator

In most cases, SCADA/ADMS functions shall be provided by integrating with the SituTB SCADA/ADMS

system. In some cases it may simplify configuration to use a SCADA simulation tool. This tool would be a

test set for the SCADA protocol – IEC 60870-5-104 or DNP3 – acting as the Master and issuing control

commands to the system under test.

SASTB DATB

Situational Awareness Test Bed – System Components

SCADA

CollectProcess

Store

Data Acquisition Front End

(DAFE)

Web Server System(WSS)

ADMS Access via

web browser(Read Only)

ADMS Applications

NTPUBPFFLISRV-V-C

ReconfigOMS

User Interface

Video WallWorkstation

Printers

Modeling

Maintain the Network

Operational Model(NOM)

Data Historian

(DHS)

Long term archive of

data as received by

SCADA

Remote Access(RAS)

Contractor maintenance interface to

ADMS

CPRI Network

Router -VPNw/Firewall

Small Simulation

Realy Test Set

Simulator in SGTB

Generic Direct

To any CPRI location with

Campus Network Access

Generic External

To any CPRI location without Network Access

Transformer Pad

To 11kV devices on the SGTB XFMR Pad

Router -VPN Router -VPN Router -VPN Cellular VPN

Substation Automation

System

IEC-104 to IEC 61850 Gateway

Router -VPNRouter -VPN

Environment

Production

Simulation

Programming

Management

Archive

SAS Remote Station

IEC-104 to IEC 61850 Gateway

Router -VPN

CPRI Corp Firewall

Cellular to Internet

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4.6.2 Station Level Computer

Distribution Automation schemes may be Centralized, Decentralized, or Distributed.

Centralized: depend on SCADA to collect information and send commands. Depend on

functions within the ADMS to process SCADA information and determine control actions.

Decentralized: depend on a station computer to collect information from field devices and

determine and issue control actions.

Distributed: no central control exists – intelligent devices are distributed along the feeder and

exchange information as needed. Control decisions are made in a distributed environment by

pole mounted devices.

Decentralized schemes will require a station computer configured to support the particular DA

function, such as Fault Location, Isolation, and System Restoration (FLISR). The station computer

shall match the SASTB specification details:

Station Level Computer Specification:

Adhere to requirements in SASTB section 4.1

Hardened computing platform for 19” substation rack mount

Fanless operation

IEC 61850 compatible

Windows 7 Professional or Windows 10 Pro 64 bit operating system

Multicore processor 2GHz or higher

8GB RAM or higher

Hot swap RAID spinning disk – 1TB

(4) USB 2.0 ports

PCI or PCI Express expansion slots

(4) Ethernet ports (2 needed for Dual Station LAN connection)

(2) EIA-232 asynchronous serial ports

Time synchronization to 1 microsecond using IRIB-B or IEEE1588 PTP time synchronization

Battery backed Real time clock

19” Rack Mount touch-screen monitor

230 VAC 50Hz power supply

4.6.3 Gateway

The SCADA protocol may require translation to a protocol supported by the IED used to interface to real

world signals. The DATB shall employ an embedded Gateway device rather than a software gateway on

a station computer.

Gateway Specification:

Adhere to requirements in SASTB section 4.1

Accept IEC 60870-5-104 SCADA Server protocol (RTU)

Map to IEC 60870-5-103, DNP3 or IEC 61850 Client protocol

230VAC 50Hz power

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4.6.4 Time Reference (supply scope covered under Situational Awareness test bed part of this

tender)

Integrating measurements from multiple remote locations requires GPS time synchronization. A GPS

clock shall be located at SCADA and at each remote location to maintain synchronization between

SCADA and the remote locations.

Time Reference Specification:

GPS synchronized

GPS antenna with 50ft cable

230 VAC 50 Hz power

61850-9-3 compatible

61850-3 compliant

IEEE1588 compliant PTP support

1 PPS output

IRIG-B Output +/-1 microsecond

(4) 100BaseT Ethernet ports

4.6.5 Power Supply

The SGTB building will include an uninterruptible 230VAC 50Hz supply (Building UPS). All devices on the

DATB shall be specified to operate from building 230VAC 50Hz power.

The Generic Integration Model will include a UPS for use where building critical power supply is not

available.

4.6.5.1 GIM UPS Specification (not in the scope of supply under this tender)

19” rack mounted unit

50Hz 230 VAC UPS compatible with CPRI campus grid power

Sine wav output with no more than 5% voltage THD

30 minutes backup operation of the GIM rack in the event of a loss of grid power.

Replaceable, recyclable, standard form factor batteries

3 year expected service life of batteries

Dry contact indicator of loss of AC

4.6.6 LAN Ethernet Switch

In most cases, the four (4) Ethernet ports on the remote Router will be sufficient to connect remote

devices to the DATB VPN. In cases where greater connectivity is required, devices at remote equipment

locations shall be integrated on a Local Area Network using an Ethernet Switch. One (1) switch is

required at each remote location. These include the DATB (Small Scale Simulation), the Generic Interface

Model (e.g. Large Scale Simulation at the Power Systems Lab), and the Transformer Pad.

Specification:

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o Adherence to the requirements of SASTB section 4.3.1

o IEEE1613 / IEC 61850-3 compliant (electrical and environmental stresses)

o 12 Small Form Factor Pluggable (SFP) ports for connection of all Bay Level and Process Level

devices.

o 230VAC 50Hz power supply

o IEEE 1588v2 capable

o Rapid Spanning Tree Protocol (RSTP) - IEEE 802.1d-2004

o VLAN aware - IEEE 802.1q 2005

o Multicast filtering capable

o SNMP Management version 2c and version 3

o Web-based and/or CLI (SSH) management

o Syslog Logging

4.6.7 Portable Notebook Computers (2 recommended):

Intel i7 processor or better

Windows 7 professional or Windows 10 Pro

10 hour battery life

16 GB RAM

1TB SSD drive

14” or larger outdoor-readable touch display

(1) HDMI output

(2) USB 3.0

(2) Ethernet ports (may be via USB adapter)

WiFi 802.11n

Bluetooth 3.0

4.6.8 Router

Router Specification:

IEEE1613 / IEC 61850-3 compliant

230VAC 50 Hz power

4 Ethernet ports

VPN support for connection to the SituTB SCADA System

Intrusion Detection capability

Single T1/E1 interface

Internal Cellular modem interface – LTE, 3G, GPRS

SNMP Management version 2c and version 3

Web-based and/or CLI (SSH) management

Syslog Logging

IEC 61850-9-3/IEEE 1588 PTP compliant

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4.7 Miscellaneous and Spare Parts

Ethernet cabling – (20) 100Base-TX (RJ45) and (50) 100Base-FX (Dual LC), 10’ to 25’ long

Ethernet adapters – (50) each SFP for FX (fiber optic) and TX (copper) network cable

terminations

230VAC 19” rack mount surge protected power strips

5 RTU Specification The DATB components will interface to the SCADA/DMS system in the SituTB using Routers for Layer 2

Virtual Private Network (VPN) connections to RTUs that may be installed throughout the CPRI campus as

a basis for demonstrating the capability of SCADA to directly monitor and control typical Smart Grid and

substation equipment. Where the CPRI campus network is not available (e.g. in the 220kV substation or

in remote campus locations) the Router internal 3G/4G cellular modem will be used to establish the VPN

to ADMS. The RTUs shall support two-way data communications with the SCADA component of the ADMS

over the VPN. In this respect, the ADMS and RTUs shall normally communicate over CPRI’s optical fiber

IP-based WAN. The data communication protocols supported by the RTUs shall include:

1. IEC 60870-5-104

2. DNP 3.0

3. IEC 61850 Client

4. IEC 61850 Server

5. MODBUS RTU

5.1.1 Data Acquisition

In accordance with each communication protocol, support for data acquisition shall include:

1. Polling of the RTU by the ADMS for specified status and analog data points at configurable

scan rates or on demand.

2. Report-by-exception, i.e., polling of the RTU in such a way that for status data points only

those that have changed are sent to the ADMS and for analog data points only those that

have changed by a configurable dead band.

3. Unsolicited reporting in which the RTU sends the changed data automatically without waiting

to receive a poll command.

4. General interrogation in which the ADMS polls the RTU for all available data.

5.1.1.1 Analog Inputs

The RTU shall:

1. Acquire analog inputs directly without transducers from power system voltage and current

terminals.

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2. Apply suitable filtering to eliminate the risk of signal aliasing.

3. Use voltage and current inputs for calculations that support acquisition of the following data

as a minimum:

a. Line-to-line voltages.

b. Phase current magnitudes and phase angles.

c. Real and reactive powers (three-phase kW and kVar totals with sign).

d. Power factor.

4. Accept ac voltage input signals with a normal input level of 110 V.

5. Employ analog to digital converters with minimum of 16-bit resolution for a bipolar input

signal.

6. Accurately resolve ac voltage input signal levels from 0 to 150 V.

7. Accurately resolve ac current input signals with normal ranges of 0 to 5 A or 0 to 1 A.

8. Include the capability to report all analog values that have changed by more than their

programmable dead bands from their last values successfully reported to the ADMS.

9. Record maximum rms fault current signals, over a period of at least one (1) second, up to 20

times normal (100 A) within a maximum error of 2.5% of Full Scale Deflection (FSD).

10. Not impose a total analog input burden of more than 0.5 VA for all current and voltage inputs.

11. Demonstrate an overall analog input error of no more than ±0.2% of 1.2 times normal FSD

over the temperature range 0 to 70°C.

12. Demonstrate an analog input linearity better than ±0.05%.

13. Reject common mode ac (50 Hz) voltages up to 150 V.

5.1.1.2 Status Inputs

As a minimum, RTUs shall accept isolated wet and dry single contact two-state status inputs and two-state

status inputs with memory, i.e., Momentary Change Detection (MCD) inputs. Input changes of state shall

be timestamped to a precision of 1 millisecond.

Within this context:

1. All necessary wetting voltage, current limiting, input isolation, and bounce filtering shall be

provided.

2. Contact de-bounce time periods shall be individually configurable.

3. The input circuits shall be optically isolated from the external signal.

4. Input contact wetting voltages shall be 24 VDC as obtained from the RTU’s DC power supply.

5. Each wetting voltage circuit shall be protected with its own circuit breaker.

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5.1.1.3 Analog Outputs

RTUs shall include the capability to receive analog output signals from the ADMS such as those that may

be used to send set points to automatic voltage regulators.

5.1.1.4 Control Outputs

The RTU shall support the capability to receive commands such as those that may be used by relays to

open and close substation circuit breakers or other switches. Such commands shall include the following

control output features:

1. A Select-Check Back Before-Operate (SCBO) procedure:

a. On receipt of a control point select command, the RTU shall check that no other point

is selected, select the requested point, acknowledge the select command, and start a

Command Receipt Timer.

b. Control point selection shall be canceled if the subsequent operate command is not

received within the Control Receipt Timer’s programmable time-out period, which

shall be adjustable from five (5) to thirty (30) seconds.

c. On receipt of the operate command, if the control point has remained selected and

no other point has become selected, the RTU shall then initiate the requested control

action.

d. The SCBO procedure shall be canceled automatically on completion of the control

action or if not completed within an adjustable time-out period of up to 60 seconds.

e. Any further attempt at control shall require a new SCBO procedure.

2. Opening and closing of a switch by sending commands to a complimentary pair of contact

outputs such that:

a. One command activates the contact used to open the switch.

b. The other command activates the contact used to close the switch.

c. Only one contact output in a complimentary pair can be activated at a time.

3. Momentary control where each output provides a contact closure pulse having an individually

programmable duration from 1 to 60 seconds in increments of 1 second.

The following requirements shall also apply:

1. The voltage rating of the control output contacts shall be 24 VDC.

2. All control power shall be obtained from the RTU’s 24 VDC power supply.

3. RTU control outputs shall be able to drive loads of at least six (6) amps.

4. Output relays shall be designed for 106 (one million) mechanical operations.

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5. The RTU shall monitor all operations and local status information and give warnings or

advisory messages when any wrong operational sequence is requested.

6. Abnormal conditions shall inhibit control operations.

5.1.2 Estimating RTU Point Count

Point count in the RTU depends on the particular application. Unused points add cost to the RTU, but

allow extension of the RTU to address unanticipated need. Points are typically added by the addition of

I/O modules that each provide some number of points of one or more type.

The Generic Integration Model (GIM) will locate a router, gateway, and RTU at a remote location to

provide a mechanism for SCADA/DMA to acquire measurements and command control or analog

outputs. Typical RTU application will monitor at a single location, such as the 220kV and 33kV

substations. In such an application, an RTU with:

(16) DI

(8) DO

(16) AI

(8) AO

The GIM will also integrate the Power System Lab simulator to DMS for modeling of distribution

automation schemes. Assume a total of (20) observation/switching points across several circuits. Each

observation/switching point requires:

Digital Input (2 per location) - Switch State (Open|Closed), FPI state (Fault|NoFault)

Control Output (3 per location) - Switch Open, Switch Close, FPI Reset

Analog Input (4 per location) – Voltage, Current, Watts, Power Factor

Analog Output - Not required in most cases.

So for a total of (20) observation/switching points on a simulation model:

Digital Input 2*20 40

Digital Output 3*20 60

Analog Input 4*20 80

Analog Output 8

This large RTU might be replaced by RTU simulation by the Power Systems Lab simulator.

5.1.3 RTU Architecture

The RTU shall incorporate a programming capability within an architecture that supports convenient

installation, maintenance, and expansion features. The architecture shall include a central processing

module, I/O module, control module, communications module, and time and date module.

5.1.3.1 Central Processing Module

The Central Processing Module (CPM) shall:

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1. Support a high-level language processing capability per the open IEC-61131-3 standard for

programmable logic controllers.

2. Support management of the RTU database from a local test set.

3. Support ADMS download and upload of RTU parameters and configuration data.

4. Implement the communication interfaces with the ADMS.

5. Control data acquisition and the sending of control commands using an I/O module.

6. In accepting commands from the ADMS:

a. Perform address recognition.

b. Assemble response messages in accordance with the received command messages.

c. Transmit these messages to the ADMS.

7. Provide interfaces for a time standard and test set.

8. Manage communications between all other functional modules of the RTU.

9. Determine the integrity of the RTU.

10. Provide diagnostic information in the message structure that the ADMS shall monitor.

11. Set a flag if the RTU performs a restart for any reason including power failure.

12. Include a watch-dog timer that is reset regularly by RTU software. If the software fails to reset

the watch-dog timer (e.g., because of a software error causing the software to “loop” or

“hang”), then the timer shall expire causing the CPM to reset and restart.

5.1.3.2 I/O Module

I/O module requirements include the following capabilities and features:

1. Capability to accept analog and status inputs and send control outputs. This shall include fault

current measurements.

2. Capability of being replaced without reprogramming, redefinition of configuration

parameters, or rewiring.

3. A Control Switch (CS) that, if not in its normal control position, inhibits control from the ADMS

or test set.

4. A status input contact so that the ADMS or test set can monitor if the position of the CS is in

its normal control position.

5.1.3.3 Control Module

The RTU shall include an integrated control module that can control devices without the need for

interposing relays.

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5.1.3.4 Communications Module

The RTU shall be provided with a communications module including necessary and sufficient numbers and

types of port that can be used to support:

1. Remote data communications with external systems and devices over an Ethernet/IP

network. This shall include data communications with multiple masters.

2. Local and remote configuration with a static IP address.

3. The fully implemented message security features of the required data communication

protocols running over TCP/IP.

4. Communications that is not degraded by simultaneous activity in other parts of the RTU.

5. Temporary connection of test sets such as laptop PCs for local installation, maintenance,

diagnostic, and test purposes for all configurations and data access functions associated with

the RTU.

6. SCP/SSH with respect to downloading, for example, RTU configuration parameters and

firmware updates.

7. Features such as HTTPS for web server functionality.

8. Blocking or disabling of ports to prevent unauthorized access.

9. MAC and IP filtering so that Ethernet traffic is limited to a configurable “whitelist” of network

device MAC and IP addresses.

10. Access control using a secure log-in procedure. As a minimum, this shall include user

authentication based on a unique username and password.

11. System logging (syslog) at a device or system level. Syslog alerts shall include remote user

access activity including successful and unsuccessful login attempts.

12. Manual configuration of a routing table with different metrics so that networks may be

reached using locally entered alternative paths (IP redundant paths for example).

5.1.3.5 Time and Date Module

The RTU’s time and date module shall:

1. Include an internal time-of-day clock for data collection coordination. The time resolution of

the internal clock shall be one (1) ms or better and, without synchronization, the time shall

drift by no more than 5 ms per hour.

2. Use the RTU’s 24 VDC power supply as the only source of power for the internal clock, i.e., no

other source such as an internal (on-board) battery shall be used.

3. Synchronize the internal clock whenever the RTU is powered up. This shall not prevent the

RTU from immediately registering inputs even before the time and date reference signal has

been received. Any such inputs shall be reported to the ADMS with the appropriate time and

date, i.e., use of an arbitrary default time and date is not acceptable.

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4. Support receipt of a DNP 3.0 compliant time and date message that contains a Greenwich

Mean Time (GMT) reference signal, generated by the ADMS in long format and in such a way

as to properly account for communication path delays.

5. Support capability to synchronize the internal clock to the GMT time and date received from

the ADMS.

6. Support capability to synchronize to an optional Global Positioning System (GPS) receiver. The

GPS antenna shall be of low profile type for secure and moisture-resistant mounting on top

of the RTU enclosure. The receiver shall be used to synchronize the internal clock to the

correct GMT time and date within a time resolution of at least 1 millisecond.

5.1.4 Power Supply

The RTU shall include an integrated 24 VDC regulated and protected power supply with source power

from the 230 VAC 50 Hz mains. It shall be used to power the RTU and its local control panel. It shall also

be capable of powering local test sets from an RTU enclosure power receptacle. The supplier shall be

responsible for determining its maximum output capability.

5.1.4.1 Batteries

Under normal conditions, the DC power supply shall connect to a substation 230 VAC power supply. As

backup, however, it shall be powered by a 24 VDC maintenance-free rechargeable battery with the

following characteristics:

1. Be of lead-acid gel electrolyte type.

2. Be designed and tested per IEC 60896-21, DIN 43534, BS 6290 Part 4, or equivalent.

3. As a minimum, have sufficient capacity to sustain operation of the RTU and its local control

panel for not less than twelve (12) hours if the ac power source fails.

4. Be designed using an appropriate temperature correction factor, design margin, and ageing

factor.

5. Have a minimum lifetime of not less than 8 (8) years at a nominal temperature of 20 °C.

5.1.4.2 Battery Chargers

The DC power supply shall include an intelligent battery charger, which shall:

1. Be of switched-mode 100-240 VAC power input type.

2. Be fully temperature compensated.

3. Be automatically switched to charging mode when the battery voltage drops below a preset

value and, in the following cases, be automatically switched to a “do not charge” trigger

mode:

a. Battery voltage is over the preset value.

b. Ambient temperature is more than 60 °C.

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c. Charging time is more than a configurable number of hours, e.g., twenty-four (24)

hours.

d. Battery exhibits a high impedance (battery failed) condition.

4. Have over current, over voltage, and surge protection.

5. Prevent deep discharge of the battery on loss of the AC power source. In this respect:

a) The battery charger shall automatically disconnect all circuitry fed by the battery

following a user-adjustable time or when the battery voltage falls below a preset

value.

b) The time to fully recharge the battery once disconnected from load shall not exceed

twenty-four (24) hours.

c) The direct current power will be cut off when voltage stays under the minimum

preset value.

In addition to the above requirements, the capability to initiate the following alarms shall be provided:

1. Low battery voltage alarm.

2. High battery voltage alarm.

3. Battery failed alarm.

4. Battery charger overvoltage alarm.

5. Battery disconnected alarm.

Each alarm indication shall be displayed on the RTU’s local control panel with super bright LED pilot lamps.

These alarms shall be reported to the ADMS as an event.

5.1.5 Local Control Panel

The RTU shall include a local control panel, which shall include:

1. A mimic diagram and facilities for operation of RTU local control functions.

2. An A/C power supply on/off switch. When the A/C power source is off, operation of the RTU

shall be possible by using its battery backup feature.

3. A Local/Remote switch. While this switch is in the “Local” position, control shall be permitted

only from the local control panel (i.e., remote control shall be prohibited). Otherwise, while

the switch is in its “Remote” position, control shall be permitted only from the ADMS (i.e.,

local control shall be prohibited).

4. LED lamps for RTU, battery, battery charger, and local/remote status indications.

5. Battery voltage test points.

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5.1.6 RTU Software

The term “software” is used to mean software or software implemented through firmware. Complete and

comprehensive documentation shall be provided for all software.

5.1.6.1 Operating System

The RTU operating system shall:

1. Be a real-time non-proprietary operating system.

2. Manage and support all RTU applications.

3. Support editing and customization as needed to maintain RTU operation.

4. Provide automatic restarts of the RTU on power restoration, memory parity errors, hardware

failures, and manual request.

5. Initialize the RTU on power-up and begin execution of the RTU functions without intervention

by the ADMS.

6. Report all restarts to the ADMS.

5.1.6.2 Operating Software

The RTU operating software shall be:

1. Prepared in a high-level language such as the IEC61131 programming suite.

2. Documented in detail.

3. Free of additional licensing charges or license agreements.

4. Supported by protocol, configuration, and application data contained in easily programmable

non-volatile memory such as Flash EPROM.

5. Independent of any data communications protocol that would impose restrictions on the

flexibility or functionality of the RTU. In this respect, protocol changes shall be capable of

being accomplished by locally and remotely implemented software/firmware changes only.

5.1.6.3 Diagnostic Software

RTU diagnostic software shall:

1. Continuously monitor operation of the RTU.

2. Report RTU hardware errors to the ADMS.

3. Check for memory, processor, and input/output errors and failures.

4. Be sufficiently detailed to detect malfunctions to the level of the smallest replaceable

component.

5. Facilitate isolation and correction of all failures.

6. Include features promoting rapid fault isolation and component replacement.

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7. Include integrated on-line diagnostic functions in all functional module nodes.

8. Report diagnostic results to the CPM for store and forward to the ADMS.

5.1.7 Enclosures

The RTU equipment, including local control panel, batteries, and battery charger, shall be housed in a

suitable enclosure.

To safeguard against outdoor installation, the enclosure shall prevent moisture condensation including

corrosive salt formations and the ingress of rain water, airborne dust, vermin, and small objects. It shall

be designed to ensure that it remains rigid and retains its structural integrity under all operating and

service conditions with and without the door being closed. In this respect, it shall be fabricated from

stainless steel panels (Type 304L) of not less than 2 mm in thickness, and the door opening shall have a

perimeter flange with a rubber or neoprene gasket. The finishing coat shall be grey (RAL 7032).

A pocket attached to the inside of the door shall be provided to hold documentation such as maintenance

log sheets, control unit diagrams, and operating instructions. The door shall be opened by a single handle,

which shall be capable of being locked by use of a padlock and key. A means to remotely monitor the

open/closed status of the enclosure’s door shall be provided. An equipment alarm shall be generated

whenever the door is opened.

The enclosure shall include a grounding terminal with grounding bolt and lock washer for connecting a 50

mm2 galvanized steel grounding conductor. The grounding bolt and lock washer shall be made of stainless

steel.

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6 Physical Structure (Rack)r DATB hardware shall be mounted in 19-inch two-post relay racks. The structure shall

consist of one (1) 19” x 45U two-post rack on casters for mounting of the Transient

Simulator and interface devices. The test equipment rack will be suitably stable to

allow rolling movement of the rack without risk of tipping over. Two such racks are

required – one for DATB and another for remote equipment at the Power Systems

Lab.

Rack Specification: Total (2) racks

19” 2-post relay rack

12-24 OR M6 threaded holes

Black finish

Formed steel OR Extruded aluminum construction

1000 lbs (455 kg) weight capacity

Base dimension approximately 20”x14”

Top cross member width 6”

Outside dimension approximately 20”

Threaded hole spacing 18.312” (465mm)

Inside clearance 17.81” (452mm)

Concrete floor installation kit Rack Accessories

(qty 1000) compatible rack screws

(qty 2) 3U 2-post shelf

(qty 2) rack caster sets for mobility of (2) racks

(qty 2) 20 amp rack mount AC surge suppression power strip, individually switched universal power socket

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Figure 6-1 Rack mounts for DATB Equipment

7 Communication Network Communications within the CPRI campus shall utilize the CPRI backbone IP Network.

7.1 Network Performance Requirements

The DATB LAN and the SituTB WAN connections shall be 100/1000 Mbps Ethernet. The performance of

the overall network architecture shall be such that the critical clearing time requirements for various

control functions are guaranteed under all network loading conditions. The network performance shall

be completely predictable for operational behaviour.

Fiber optic cabling shall be used in the DATB equipment. Integrator shall provide all required fiber optic

cables, with a set of spare fiber optic cables sufficient to connect two additional IEDs to each rack.

7.2 Connection from DATB to the SGTB external transformer pad

Communication from DATB to equipment on the SGTB transformer pad shall be by fiber optic link to a

weather tight enclosure securely mounted on the transformer pad. 2” or larger conduit from DATB to

the transformer pad enclosure shall be installed. Pre-terminated indoor/outdoor 12 strand multimode

flat drop fiber optic cable pulled through the conduit shall terminate on each end at a panel of six dual

LC fiber terminations. Alternatively, CPRI may choose to field terminate the twelve fiber strands into the

dual LC terminations.

19" x 45U Rack structure for DATB equipment mount.NTS - Color only denotes intended use – all racks are black.

Racks 1 and 2 are on casters for mobility.

84

" (45

U)

Rack 1DATB

Rack 2PS Lab

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7.2.1 Fiber Link Specification

Option 1 - traditional field-termination: Cable:

OM2 or OM3 50/125 µm Multimode fiber Indoor / Outdoor rated 12-fiber count Loose Tube buffering, gel-free

Fiber Termination (Multiply by two in order to terminate both ends of cable): Small termination enclosure, single panel LC Connector pigtails (Qty 12) Connector panel w/ 6 duplex LC-Type connectors (Based on enclosure) Heat Shrink Splice Cover (Qty 12)

Option 2 - Use Connectorized cable with pre-terminated housing: Housing with 6 multimode Duplex-LC connectors pre-terminated to a 12-fiber multi-fiber connector (Quantity 2) Indoor/Outdoor OM3 50/125 µm multimode cable terminated with 12-fiber multi-fiber connector

7.3 SNMP Manager All DATB network components shall include an SNMPv3 Agent for device management by an SNMP

Manager. DATB shall include an SNMPv3 management system installed on the SituTB Workstation

Computer. Additional SNMP Managers may be installed on the DATB Portable Computers. Several

SNMP Managers are available at no or low cost for a system as small as SASTB:

SNMP Manager shall

Automatically detect network devices

Map network topology

Monitor for events (faults, availability, and performance) of network devices

Send event alerts via console display and email

Sequentially timestamp log entries

Provide search capability through system logs

Concurrently manage a minimum of 50 network devices

Run on the Windows 7 or Windows 10 station and portable computers

7.4 Redundancy Requirements

The DATB will not require redundancy in hardware or software.

7.5 Cyber Security Requirements for Distribution Automation

DATB shall utilize the existing CPRI campus IP network, with commercial cellular modems for off-campus

communication needs. Connection from the SGTB building to other campus buildings shall be by Virtual

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Private Network (VPN), with VPN supporting routers at each end of the connection. Connection to off-

campus locations shall be by VPN over cellular modem (see Figure 4.3).

The exchange of any information between systems shall include authentication of BOTH the source and

the receiver.

For communications using IEC 60870-5-104, the IEC 60870-5-7 standard that references IEC 62351-5 and

IEC 62351-3 shall be met.

Cryptographic key management shall be provided based on IEC 62351-9 requirements. Alternatively,

Public Key Infrastructure (PKI) may be used for key management.

Compliance with the cyber security recommendations in IEEE 1686 is required, including user ID and

password control, testing for adequate password strength, provision of audit capabilities for alarms and

events, monitoring of security-related activities, appropriate cryptographic technologies, and IED

configuration management.

8 Reliability and Availability vs. Flexibility The DATB is designed to provide a high level of testability and flexibility. IEDs and test equipment shall

be added and deleted from the DATB local and remote fixtures by CPRI Staff on a regular basis. As a

result, availability and reliability will be more a factor of the diligence of the operators than to the

quality of the components. Functional failures will not affect physical line hardware. The design will

stress this need for flexibility rather than extreme availability common in utility installations. Redundant

Requirements and definitions for reliability are defined in IEC 60870-4, chapter 3.1.

9 Contracting Options CPRI has three options in realizing the DATB:

Purchase, take delivery, assemble, and commission the DATB with internal CPRI staff.

Purchase and take delivery of the DATB hardware and software, then contract a knowledgeable

consultant to assemble and commission the DATB with assistance from UARC engineering staff.

Consultant would then provide training to UARC staff. Estimated 6-8 weeks manpower.

CPRI can contract the DATB to a Turnkey Contractor to assemble and commission the DATB for

delivery as a complete and working unit. A consultant would then be engaged to train UARC

staff on operation of the DATB. Conventional estimates for turnkey work are 1/3 material, 1/3

labor, and 1/3 profit, so a Turnkey assembly can be estimated as adding 2 * (material cost) to

the overall project cost.

The scope of work of the DASTB Turnkey Contractor shall include physical assembly, IED configuration,

and provisioning of 61850 SCL files as needed. It shall also include the engineering of the GOOSE and

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Sampled Value messages as required to implement the protection schemes, connection to the SituTB

SCADA WAN, and delivery and set-up of the DATB.

Design, installation, and commissioning of the 11kV Transformer Pad equipment and the 12-strand fiber

network connection from DATB to 11kV transformer pad will require a qualified integrator. This item is

to be contracted independent of the purchase of the balance of the DATB equipment.

10 Feature Quantities: Table 10-1 DATB Features List

# Feature Qty Section Notes

1 Rack Structure 2 6 19"x45U, (4) on casters

2 Router 4 4.6.8 Allow for (4) remote connections

3 Ethernet Switch 4 4.6.6 Each remote connection

4 Station Computer 1 4.6.2 Host for (1) Decentralized DA Scheme

5 Gateway 4 4.6.3 60870-5-104 to DNP3 or 61850

6 Remote Terminal Unit (small) 4 5 (16) DI, (8) DO, (16) AI, (8) AO

7 Remote Terminal Unit (large) 1 5 (40) DI, (60) DO, (80) AI, (8) AO

8 Portable computer 2 4.6.7 Dual LAN adapters

9 SituTB SCADA simulator 1 4.6.1 60870-5-104 master on laptop

10 SNMP Manager 1 7.3

11 12 strand fiber network link 1 7.2 CPRI Field Splice

12 Small Scale Simulation capability

1 4.2.1 Use Existing SASTB unit

11 Mapping Functions to Features (only for information) DATB enables CPRI to perform a list of Functions as specified in section 3. Each Function depends on a

subset of test bed Features. Each Feature has a cost associated with it. As funding permits, CPRI will

select “Buy”, “Use Existing”, or “Delay” for each Feature (Table 13-1). In this section we will create a

mapping of Functions to the required Features. This mapping will be used to populate the Function vs.

Feature Matrix (Table 11-2).

The Design of the DATB has generated a list of 15 Features to support 7 different Functions as itemized

in Table 11-2. This matrix will be manipulated in an Excel Spreadsheet to select the Features to be

realized.

Available Add Cost

Buy Yes Yes

Use Existing Yes No

Delay No No Table 11-1 Selection options for each Feature

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Function List DATB Functions

Rac

k St

ruct

ure

Ro

ute

r

Eth

ern

et S

wit

ch

Stat

ion

Co

mp

ute

r

Gat

eway

Smal

l RTU

Larg

e R

TU

IEEE

15

88

tim

e so

urc

e

23

0 V

AC

UP

S

Po

rtab

le c

om

pu

ters

Situ

TB S

CA

DA

sim

ula

tor

Stan

dar

ds

for

refe

ren

ce

SNM

P M

anag

er

11

kV t

ran

sfo

rmer

pad

eq

uip

men

t

12

str

and

fib

er n

etw

ork

lin

k

Smal

l Sca

le S

imu

lati

on

cap

abili

ty

Wir

esh

ark

for

pac

ket

cap

ture

3.4.1 Generic Interconnection Model

3.4.2 Small scale simulation

3.4.3 Large scale simulation

3.4.4 Integration with SituTB SCADA/DMS

3.4.5 Integration with transformer pad switchgear

3.4.6 Observe 220kV and 33kV substation operation

3.4.7 Monitor information flow

Table 11-2 Function dependency on Features

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