Attachment_2_SOW_UpgradeSubStationRelays.pdf

Substation Relay Upgrade

1. Statement of Work

1. Remove and replace all electromechanical relays in the entire 12 KV switchgear located in 60 KV substation with equivalent digital relays. Make – General Electric/ Schneider Electric.

2. Remove and replace all cubicles front doors of entire 12 KV switchgear with prewired UL approved front doors. New front door shall have all new components including but not limited to digital relays, CT/PT test blocks, VCB control switch, Lockout relay switch, LED indicating lamps, name plates etc. Front door shall be manufactured and prewired at supplier manufacturing unit and delivered at site with pig tail wires ready to be connected to switchgear terminal blocks.

3. All front doors without any relays shall also be replaced to match with other new cubicle doors.

4. All existing relays shall be tested by NETA certified technicians to verify relay settings. Test report shall be part of deliverables.

5. All new relays shall be tested and commissioned at site to verify new relay settings by NETA certified technicians. Test report shall be part of deliverables.

6. Contractor shall get the entire switchgear UL certified after new front doors of all the bays have been replaced.

7. Contractor shall field verify all switchgear details at site and verify that they match with the switchgear drawings. Government shall not be liable for any ambiguity between switchgear as built drawings and field conditions.

8. Contractor shall provide as built drawings to show wiring drawings of all new relays and other new components of all the cubical doors.

9. New cubical front doors shall be factory power coated and of same color, material and thickness as existing switchgear. It shall also have single line diagram of entire switchgear embedded in red and exactly match existing switchgear configuration.

10. Contractor shall provide any additional wiring, termination etc. required to use/activate all the relay characteristics mentioned below which may not be currently in use.

2. Feeder Protection Relay characteristics

1.0 Protection, monitoring and metering shall be supplied in one integrated digital relay package for application to feeders suitable for incorporation into an integrated station control system.

1.01 The Digital Relay shall have a common Hardware and Firmware platform that shall support Feeder, Motor, Transformer and Generator applications.

SP330018B0006

Attachment 2

1.02 The Protection and Control unit shall include an LCD display unit for Human Machine Interface (HMI) that indicates: measurement values, operating messages, and device maintenance messages.

1.03 The display unit shall have, as a minimum, 4 lines for clear annunciation of alarm conditions.

1.04 The relay shall have a mimic-based display and an option for a remote display.

1.05 The Protection and Control unit shall be able to be removed from service without disconnecting any wires from the relay.

1.06 The Protection and Control unit shall allow front face connection via a standard USB connection cable.

1.07 The Protection and Control unit shall support a matrix style for custom assignment without requiring structured text programming.

1.08 The Protection and Control units shall be conformal coated.

1.09 The Protection and Control unit shall be UL Recognized in US.

1.08 The Protection and Control unit settings software shall be provided at no cost.

The relay shall be equipped with the following protection monitoring, control, automation, and reporting functions.

1.1 Protection and Control

A. The relay shall provide the following current based protection functions.

1. Undercurrent (37)

2. Phase/Neutral/Ground Instantaneous Overcurrent (50P/N/G)

3. Sensitive Ground Instantaneous Overcurrent (50SG)

4. Phase/Neutral/Ground Time Overcurrent (51P/N/G)

5. Sensitive Ground Time Overcurrent (51SG)

6. Negative Sequence Instantaneous Overcurrent (50_2)

7. Negative Sequence Timed Overcurrent (51_2)

8. Phase/Neutral Directional Overcurrent (67P/N)

9. Ground Directional Overcurrent (67G)

10. Sensitive Ground Directional Overcurrent (67SG)

11. Negative Sequence Directional Overcurrent (67_2)

12. Restricted Ground Fault (87REF)

13. Breaker Failure (50BF)

14. Switch On To Fault (SOTF)

15. Thermal Overload (49)

16. Cold Load Pickup (CLP)

17. Broken Conductor

18. Load Encroachment

B. The time overcurrent and instantaneous overcurrent elements can be selected to operate either on RMS or Fundamental value.

C. The relay shall provide the following voltage based functions.

1. Phase Overvoltage and Phase Undervoltage (59P, 27P)

2. Auxiliary Overvoltage and Auxiliary Undervoltage (59X, 27X)

3. Undervoltage Reactive Power (27Q)

4. Timed Undervoltage (27T)

5. Neutral Overvoltage (59N)

6. Negative Sequence Overvoltage (59_2)

7. Neutral Admittance (21YN)

8. Directional Power (32)

9. Wattmetric Ground Fault (32N)

10. Overfrequency/Underfrequency (81O/81U)

11. Fast Underfrequency

12. Rate of Change of Frequency (81df/dt)

13. Synchrocheck (25)

D. The relay shall provide the following control functions.

1. 4 Shot Auto Reclose (79)

2. VT Fuse failure (VTFF)

3. CT Supervision

4. Breaker Failure

5. Manual Close Blocking

6. Firmware configured Main-Tie-Main Bus Transfer logic

7. Undervoltage Restoration (Reactive Power)

8. Undervoltage Restoration

9. Underfrequency Restoration

E. The relay shall have integrated arc flash detection using light sensors supervised by over current to reduce incident energy yand equipment damage.

F. The relay shall have 4 Programmable Flexcurves with graphical manipulation of the individual points.

G. The relay shall have an ability to build trip and alarm matrices and directly assign corresponding output relay without using programmable logic.

H. The relay shall have configurable option to select any protection elements to be used as a trip, alarm or latched alarm function without using programmable logic.

I. The relay shall have 6 switchable setting groups for dynamic reconfiguration of the protection elements due to user-defined conditions.

J. The relay shall support 8 Flex elements that can use any available/calculated analog parameters within the relay (e.g.

comparator, inverter, over/under, etc.)

K. The relay shall support up to 16 Digital Counters.

L. It should be possible to test the Binary Inputs, Outputs and protection functions without the need for an external test kit.

1.2 Programmable Logic

A. The relays shall support 1024 lines of user defined logic to build control schemes supporting logic gates, timers, non-volatile latches.

B. The programmable logic in the relay shall be executed at 8 times per power system cycle

C. The relay configuration tool shall have embedded graphical user interface to build programmable logic.

D. The relay shall support 96 Virtual Outputs + 64 Virtual Inputs

E. The relays shall support Logic designer and Logic Monitor – i.e.

graphical logic editing tool and online monitoring of logic states in a graphical way.

1.3 Communications/Integration

A. The relay shall support the following communication protocols:

Modbus RTU, Modbus TCP/IP, IEC 61850 GOOSE, IEC 61850 Ed 2 MMS, DNP 3.0, IEC 60870-5-104, IEC 60870-5-103, OPC-UA.

B. The relay shall have the ability to configure both protection and IEC61850 related settings directly from a single setting (IEC 61850-6 based XML format) file. There shall be direct uploading of a single IEC 61850-6 based XML file into the relay. There shall be no further proprietary file format conversion required.

All setting managements through a single IEC 61850-6 based file shall be supported.

C. The relay shall support up to eight IEC61850 concurrent client connections.

D. The relay shall support GOOSE Analog reception and transmission.

E. The relay shall support up to 128 Virtual Outputs and Virtual Inputs over GOOSE

F. The relay shall support file transfer protocol TFTP and file transfer through 61850.

G. The relay shall support multiple time synchronization sources such as IRIG-B, IEEE 1588 and SNTP (2) with the ability to configure priority for the time sources and dynamically switch based on the availability of each source.

H. The relays shall provide two copper/fiber optic Ethernet ports with two modes of operation – fail over mode or independent mode.

I. The relays shall support networks for IEC62439/PRP (Parallel Redundancy Protocol).

J. The relay shall have an option for Wi-Fi (IEEE 802.11 b/g/n) connectivity to configure settings and retrieve operational records.

K. A front panel USB port shall provide connectivity to configure settings and retrieve operational records.

L. The relay shall provide a User Definable Memory Map.

M. The relay shall support Modbus connectivity to slave devices to gather data.

1.4 Relay Configuration/Setting File Management

A. Setting the entire relay from only a single setting file shall be supported.

B. The entire relay settings (not only communication related but also protection and control functional settings) shall be part of the same single setting file.

C. The relay shall be configured through IEC 61850-6 standard based Configured IED Description (CID in XML) format file only.

D. There shall be only a single relay setting (i.e. CID based XML format) file which can be directly uploaded into the device. This means there is no intermediate conversion of any proprietary setting file formats which require managing multiple settings files for just one relay.

E. The relay shall be able to receive single configuration/setting file from any third party tool (not only from a vendor specific proprietary relay configuration tool).

1.5 Front Panel Visualization

A. User interfaces shall provide a large color LCD front panel display and navigation keys.

B. The front panel shall have color LCDs to display up to 6 configurable Single Line Diagrams (SLD), 12 control objects, 15 status & 15 metering objects with a provision to control the breakers, switches, contactors and display of online metering and status information.

C. The front panel shall be capable of displaying measured values, calculated values, I/O status, device status, target messages, events, motor learned data and configured relay settings.

D. The front panel shall have support for breaker and switch control through the single line diagram and pushbuttons with Select-Before- Operate mechanism.

E. The front panel shall have a minimum of 10 user-programmable LEDs and pushbuttons.

F. The relay shall provide up to 36 configurable annunciation indicators like an annunciator panel to monitor and reset alarms through the front panel.

G. The relay shall provide configurable 20 soft pushbuttons that are controlled from the front panel of the relay.

H. The relay shall provide 10 programmable home pages.

1.6 Monitoring & Diagnostics

A. The relay shall provide Breaker Health Monitoring features including: Breaker close and breaker open times, Trip/Close circuit monitoring, Spring charging time, Per-phase arcing current, and Trip counters.

B. The relay shall record its exposure to temperature, humidity and surge. In addition, a report shall be retrievable via the communication ports on the minimum/maximum average of those recorded values. The relay shall provide Environmental awareness statistics that trends temperature, humidity and surge pulses.

C. The relay shall provide information on the power factor of the protected device (55).

D. The relay shall provide up to 64 digital channels and up to 16 analog channels of oscillography at a sampling rate of 128 samples per cycle.

E. The relay shall provide a fault report with the option for fault locator.

F. The relay shall provide configurable Event Records - with a record of the last 1024 events, time tagged with a resolution of 1 ms.

G. The relay shall store all its recorded data in non-volatile memory.

H. The relay shall provide a separate data logger function which shall record a maximum of 16 Analog channels with a settable sampling rate of 1 cycle, 1 second, 30 seconds, 1 minute, 15 minutes, 30 minutes or 1 hour including a trigger source of sample, min, max, mean.

I. The relay shall provide Pulsed output that provides 4 energy measurements

J. The current metering accuracy shall be at +/- 0.25% of the reading for up to 2 times the rated secondary current and +/- 1% for above that.

K. The voltage metering accuracy shall be at +/- 0.5% of the reading from 15 to 208V.

L. The power metering accuracy shall be at +/- 1% of the reading.

M. The frequency metering accuracy shall be typically at 1 milli hertz accuracy level.

1.7 Hardware

A. The protection relay shall provide analog input systems that can reproduce up to 46 times CT rating RMS symmetrical. The relay shall execute protection related main algorithms at 8 times per power system cycle.

B. The relay shall provide support up to 22 Digital Outputs + 57 Digital Inputs

C. The relay shall support a minimum of 4 High Speed High Break contacts + 18 Digital Outputs + 57 Digital Inputs

D. The relay shall have conformal coated electronic board assemblies for harsh environment deployment.

E. Microprocessor based protective relays shall employ IPC (Institute for Interconnecting and Packaging Electronic Circuits) Class 3 printed circuit boards (PCB) i.e. IPC Class 610-3.

F. The relay shall have a draw-out construction to facilitate testing, maintenance and interchange flexibility.

G. The relay shall provide a field swappable (i.e. removable) power supply module. There should be no electrolytic capacitors in power supply.

H. The relay shall have a scan rate of 128 samples per power system cycle for digital inputs and provide less than a 1 millisecond time stamp resolution for state changes.

I. The relay shall provide an Operating temperature range of -40° to +60°C and be tested per IEC 60068 for 16-hour operation between -40° and +85°C.

J. The relay shall provide built-in Trip Coil and Close Coil supervision.

K. The Digital Inputs shall be capable of accepting wet or dry input signals. In cases where an external wetting voltage is used, the Voltage Threshold shall be software selectable for 24V, 48V, 125V and 250V DC sources.

L. The relay contacts should be rated for a minimum of 10A continuous.

M. The relay shall support 7 dcmA outputs, 4 dcmA inputs

N. The relay shall support a total of 12 RTDs.

O. The relay shall have integrated arc flash protection with support for up to 4 Arc flash sensors.

1.8 Security

A. The relay shall provide an option for RBAC (Role based access control) with three roles such as Observer for accessing operational data, Operator for opening/closing of breakers, and Administrator for configuring the relay.

B. The relay shall provide an option for password complexity.

C. The relay shall provide an option for local device level authentication and for remote server authentication using RADIUS.

D. The relay shall provide optional support for SYSLOG to publish security related events.

E. The relay shall support secure file transfer protocol (SFTP).

F. Security Setting Reports must include the following events with time stamp.

1. Failed Authentication

2. User lock out

3. Setting changes

4. Login

5. Logout

6. RADIUS server unreachable

7. Clear Event/Transient/Fault records

G. The relay shall provide SSH tunneling connection.

1.9 Measurement – The protection and control unit shall provide metering measurements meeting the minimums listed below:

Measurement Specifications

Measurement Range

Accuracy

RMS Phase Current 0.025-50 x In I ≤ 1.5 x In: ± 0.5% of value or ±15mA I > 1.5 x In: ± 3% of value

RMS Earth Fault Current

0.003-2 x In I ≤ 1.5 x Igf: ± 0.3% of value or ±0.2% of Igf I > 1.5 x Igf: ± 3% of value

RMS Line-To-Line Voltage

0.005-1.7 x Vn

± 0.5% or ±0.3V

RMS Phase to neutral voltage

0.005-1.7 x Vn

± 0.5% or ±0.3V

RMS Active Power (PF > 0.5)

±0.1-1.5 x Pn ± 1% for range 0.3-1.5 x Pn ± 3% for range 0.1-0.3 x Pn

RMS Reactive Power

(PF > 0.5)

±0.1-1.5 x Qn ± 1% for range 0.3-1.5 x Qn ± 3% for range 0.1-0.3 x Qn

PMS Apparent Power

(PF > 0.5)

±0.1-1.5 x Sn ± 1% for range 0.3-1.5 x Sn ± 3% for range 0.1-0.3 x Sn

Frequency 16-75 Hz ±10 mHz

Fundamental Frequency Current Values

0.025-50 x In I ≤ 1.5 x In: ± 0.5% of value or ±15mA I > 1.5 x In: ± 3% of value

Fundamental Frequency Voltage values

0.005-1.7 x Vn

± 0.5% or ±0.3V

Fundamental Frequency Active, Reactive, and apparent power values

±0.1-1.5 x ± 1% for range 0.3-1.5 ± 3% for range 0.1-0.3

Power Factor ±2° or ±0.02 for PF > 0.5 Active Energy ± 1% for range 0.3-1.5 x EPn

± 3% for range 0.1-0.3 x EPn Reactive Energy ± 1% for range 0.3-1.5 x EQn

± 3% for range 0.1-0.3 x EQn

2.0 Service and Support

A. Warranty: The relay shall include a ten-year warranty for all material and workmanship defects.

3.0 General requirements

1. Contractor shall have minimum of 20 years of similar relay manufacturing, installation, testing and commissioning experience.

2. Contractor shall supply two spare relays of each kind and two spare all other electrical components including but limited to switches, CT/PT test block etc.

3. There are three 12 KV independent distribution circuits. Each circuit and corresponding cubicles will be isolated one at a time. Other cubicles will still be energized. Every power switching will require a notice of minimum of seven days. Testing, commissioning and putting back relays of each circuit in service shall be done on weekends or government approved holidays.

4. Entire project shall be completed without complete shut down of existing switchgear

5. Any power shut down requirement shall be coordinated with plant personnel and require a notice of minimum of 14 days.

6. Government shall perform power switching to isolate work area.

7. All work requiring power shut down shall be done on weekends and holidays approved by the government.

8. All testing shall be performed as per NETA specifications and NETA certified personnel.

9. All work shall be done as per applicable engineering, construction, testing, maintenance, and safety codes.

10. Appropriate PPE will be required to perform work near energized cubicles.

11. Contractor shall provide minimum of 8 hours of training to operate, program and maintain all relays and other related components.

G. The relay shall provide SSH tunneling connection.