Attachment_3_Specifications_and_Drawings_UpgradeSubstationRelays.pdf

UPGRADE HIGH VOLTAGE SUBSTATION RELAYS

SPECIFICATIONS

June 2018

DEFENSE LOGISTICS AGENCY, SAN JOAQUIN, CA

TRACY, CA 95304

SPECIFICATION INDEX

DIVISION 00 – LIST OF DRAWINGS

Section 00 01 15 List of drawings Section 00 01 00 Buy American Act Requirement

DIVISION 01 – GENERAL REQUIREMENTS

Section 01 01 10 Work Summary Section 01 14 00 Work Restrictions Section 01 32 01 Project Schedule Section 01 33 00 Submittal Procedures Section 01 35 29 Safety and Occupational Health Requirements Section 01 45 00 Contractor Quality Control Section 01 50 50 General Requirements Section 01 57 19 Environmental Protection Section 01 78 00 Project Closeout

DIVISION 26 – ELECTRICAL

Section 26 05 00 Common work results for electrical

SP330018B0006

Attachment 2

UPGRADE HIGH VOLATGE SUBSTATION RELAYS DDJC

SECTION 00100 - BUY AMERICAN ACT REQUIRMENT

Page 1/2

DIVISION 00 - PROCUREMENT AND CONTRACTING INSTRUCTIONS

SECTION 000100

BUY AMERICAN ACT REQUIRMENT

NOTICE OF BUY AMERICAN ACT REQUIREMENT-- CONSTRUCTION

MATERIALS UNDER TRADE AGREEMENTS (JAN 2005)

(a) Definitions. ``Construction material,'' ``designated country construction material,'' ``domestic construction material,'' and ``foreign construction material,'' as used in this provision, are defined in the clause of this solicitation entitled ``Buy American Act--Construction Materials Under Trade Agreements'' (Federal Acquisition Regulation (FAR) clause 52.225-11).

(b) Requests for determination of inapplicability. An offeror requesting a determination regarding the inapplicability of the Buy American Act should submit the request to the Contracting Officer in time to allow a determination before submission of offers. The offeror shall include the information and applicable supporting data required by paragraphs (c) and (d) of FAR clause 52.225-11 in the request. If an offeror has not requested a determination regarding the inapplicability of the Buy American Act before submitting its offer, or has not received a response to a previous request, the offeror shall include the information and supporting data in the offer.

(c) Evaluation of offers.

(1) The Government will evaluate an offer requesting exception to the requirements of the Buy American Act, based on claimed unreasonable cost of domestic construction materials, by adding to the offered price the appropriate percentage of the cost of such foreign construction material, as specified in paragraph (b)(4)(i) of FAR clause 52.225-11.

(2) If evaluation results in a tie between an offeror that requested the substitution of foreign construction material based on unreasonable cost and an offeror that did not request an exception, the Contracting Officer will award to the offeror that did not request an exception based on unreasonable cost.

(d) Alternate offers.

(1) When an offer includes foreign construction material, other than designated country construction material, that is not listed by the Government in this solicitation in paragraph (b)(3) of FAR clause 52.225-11, the offeror also may submit an alternate offer based on use of equivalent domestic or designated country construction material.

(2) If an alternate offer is submitted, the offeror shall submit a separate Standard Form 1442 for the alternate offer, and a separate price comparison table prepared in accordance with paragraphs (c) and (d) of FAR clause 52.225-11 for the offer that is based on the use of any foreign construction material for which the Government has not yet determined an exception applies.

(3) If the Government determines that a particular exception requested in accordance with paragraph (c) of FAR clause 52.225-11 does not apply, the Government will evaluate only those offers based on use of the equivalent domestic or designated country construction material, and the offeror shall be required to furnish such domestic or designated country construction material. An offer based on use of the foreign construction material for which an exception was

SECTION 00100 - BUY AMERICAN ACT REQUIRMENT

Page 2/2 requested-- (i) Will be rejected as nonresponsive if this acquisition is conducted by sealed bidding; or

(ii) May be accepted if revised during negotiations.

----- END OF SECTION 00100 -----

SECTION 000115 – LIST OF DRAWINGS

Page 1/1

DIVISION 00 – PROCUREMENT AND CONSTRUCTION REQUIREMENTS

SECTION 000115

LIST OF DRAWINGS

PART 1 GENERAL

1.1 SUMMARY

1.2 CONTRACT DRAWINGS

1.3 SUPPLEMENTARY DRAWINGS

1.3.1 Reference Drawing[s]

PART 1 GENERAL

1.1 SUMMARY

This section lists the drawings for the project pursuant to contract clause.

Contract drawings are as follows:

1.2 CONTRACT DRAWINGS

1. G1 – General project Location

2. SE1.2 – Substation Single Line

3. SE1.3 – Substation Relays

4. SE1.4 – Switchgear Relays

5. J9064 – Switchgear Elevation

6. 247 – Building 247

----- END OF SECTION 00115 -----

SECTION 010110 – WORK SUMMARY

PAGE 1/21

DIVISION 01 - GENERAL REQUIRMENT

SECTION 010110

WORK SUMMARY

1.1 WORK COVERED BY CONTRACT DOCUMENTS

1.1.1 Project Description

Scope of work:

CLIN 1

1.0 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, Model Multilin 850–E-PS-NN-G5-H-N-N-A-N-N-M-A-S-S-F-B-1E-S-W-B-N or approved equal.

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

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

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

6. 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.

7. Entire switchgear shall be UL certified after new front doors of all the bays have been replaced.

8. 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.

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2.0 Supply and install Feeder Protection Relay, Make General Electric, Model Multilin 850–E-PS-NN-G5-H-N-N-A-N-N-M-A-S-S-F-B-1E-S-W-B-N or approved equal with ten year warranty. Relay characteristics shall be as follows but not limited to:

2.1 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.

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

2.3 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.

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

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

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

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

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

2.9 The Protection and Control units shall be conformal coated.

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

2.11 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.

2.12 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)

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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

19. Phase reverse phase

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 Under voltage (59P, 27P)

2. Auxiliary Overvoltage and Auxiliary Under voltage (59X, 27X)

3. Under voltage Reactive Power (27Q)

4. Timed Under voltage (27T)

5. Neutral Overvoltage (59N)

6. Negative Sequence Overvoltage (59_2)

7. Neutral Admittance (21YN)

8. Directional Power (32)

9. Watt metric Ground Fault (32N)

10. Over frequency/Under frequency (81O/81U)

11. Fast Under frequency

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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. Under voltage Restoration (Reactive Power)

8. Under voltage Restoration

9. Under frequency 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.

2.13 Programmable Logic

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

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

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

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

Q. 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.

2.14 Communications/Integration

R. 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.

S. 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.

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

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

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

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

X. 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.

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

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

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

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

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

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

2.15 Relay Configuration/Setting File Management

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

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

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

HH. 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.

II. 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).

2.16 Front Panel Visualization

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

KK. 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.

LL. 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.

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

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

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

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

QQ. The relay shall provide 10 programmable home pages.

2.17 Monitoring & Diagnostics

RR. 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.

SS. 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

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relay shall provide Environmental awareness statistics that trends temperature, humidity and surge pulses.

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

UU. 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.

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

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

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

YY. 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.

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

AAA. 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.

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

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

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

2.18 Hardware

EEE. 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.

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

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

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

III. 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.

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

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

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LLL. 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.

MMM. 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.

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

OOO. 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.

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

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

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

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

2.19 Security

TTT. 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.

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

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

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

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

YYY. 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

ZZZ. The relay shall provide SSH tunneling connection.

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

Measurement Specifications

Measurement Range

Accuracy

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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

2.21 Service and Support

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

CLIN 2

3.0 Relay remote monitoring and control components

Provide remote relays monitoring and control ( as per following specifications) including but not limited to Ethernet switch, required cables, installation hardware, a radio link between 12 KV switchgear and maintenance control center CGA building 247 to monitor and control entire switchgear operations.

Ethernet switch and radio switch shall be rack mounted installed on the wall inside 12 KV switchgear building and CGA building 247. Rack location shown in the drawing are approximate. Final rack location shall be decided during project construction.

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3.1 Supply and install Department of Defense approved two rack mounted microwave data switch (MDS) Make General Electric, Model MDS iNet-II – 900 MHz MD9A1AVFCD1NN0 or approved equal with ten years warranty.

Specifications

General:

Data Rate 1 Mbps/512 Kbps user configured air link

Frequency band 902-928 MHz ISM band

Spreading mode DTS/FHSS

Range (512 Kbps) Up to 20 miles (fixed, Up to 3 miles (mobile)

Range (1 Mbps) Up to 15 miles

Radio:

System gain - 139 dB @ 512 Kbps;134 dB @ 1 Mbps

Carrier power - 100mW to 1W (20 to 30 dBm)

Output impedance - 50 Ohms

Occupied band width - 600 KHz

Modulation - CPFSK (continuos phase FSK)

Receiver sensitivity ( with 60-6 BER) – 512 Kbps – 97 dBm; 1Mbps

– 92 dBm

Physical Interface

Ethernet - 10baseT, RJ-45

Serial - COM1 RS-232/V.24, DB-9F, DCE

COM2 RS-232/V.24, DB-9M, DTE, 1,200-115,200 bps serial ports

Antenna - TNC connector (female)

LEDs - Lan, Com1, Com2, Power, Link

Protocols

Wireless - CSMA/CA (collision avoidance)

Ethernet - IEEE 802.3, ethernet II, IEEE 802.1Q (trunk, access, and native), STP, IGMP

TCP/IP - DHCP, ICMP, UDP, TCP, ARP,Multicast, SNTP, TFTP

Serial - PPP, encapsulation over IP (tunneling) for serial async multidrop protocols including Modbus, DNP.3, DF1, BSAP

MDS Cyber Security Suite, Level 4

Encryption - AES-128 with automatic key rotation

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Authentication - 802.1x, RADIUS, EAP/TLS, PKI,PAP, CHAP

Traffic segregation - 802.1Q VLAN

Management – SSL, SSH, HTTPS

Environmental

Temperature -30°C to +60°C (-22°F to +140°F)

Humidity 95% at 40°C (104°F)non-condensing

Electrical

Input power 10.5-30 Vdc, Current consumption (nominal)

Mechanical

Case - die cast aluminum

Mounting - 19” rack tray

Agency Approval

Department of Defense/ Defense Logistics Agency

FCC part 15.247 (DTS, UL/CSA class 1 Div. 21 IC, IEEE 1613

3.2 Supply and install one 20 port Ethernet Switch. Make General Electric, Model S202033PIIIII06B or approved equal with ten years warranty.

Specifications:

General

Layer 2 Managed Ethernet Switch

Media Access Control (MAC) bridges and Spanning Tree Protocol as standardized by the IEEE 802.1D

Store-and-forward packet switching

Fully flexible Ethernet switch for industrial applications, including PRP redundant networks

Ready for IEC 61850 networks

UltraRSTP (Rapid Spanning Tree Protocol - IEEE 802.1W) with fault recovery time less than 5 ms per hop (comply with IEC 61850-90-4 specifications)

Cyber Security as per NERC CIP v5 requirements

IEEE 1588v2 compliant at all ports (S2024G)

Support for IPv4 and IPv6 protocols (Multicast, Unicast and Broadcast operation)

Internal clock synchronization using NTP protocol

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Alarm contacts for detection of critical events

Standard USB 2.0 configuration port

Security

Switches shall have multi-level password protection for greater security, and to prevent unauthorized access.

SSH / SSL with 128-bit access 802.1q VLAN -provide traffic control capability for predefined ports on the switch

RADIUS and TACACS+ remote authentication Encrypted web browser Management

General Switching Characteristics

Switching Capacity 68 Gbps

Switching Latency 3 μs

Number of VLANs up to 4095

MAC Table entries up to 8192

Class of Service (CoS) levels up to 8

Networking Standards Supported

IEEE 802.3i 10BASE-T

IEEE 802.3u 100BASE-T(X)/100BASE-FX

IEEE 802.3ab 1000BASE-T(X)

IEEE 802.3z 1000BASE-SX/LX/ZX

IEEE 802.3x Full duplex operation, flow control

IEEE 802.1D Media Access Control (MAC) bridges

IEEE 802.1Q VLAN (Virtual Local Area Networks)

IEEE 802.1p Class of service

IEEE 802.3ad Link Aggregation Control Protocol (LACP)

IEC 61850

Power Substation applications

IEEE 1588 v2 PTP

IEEE Standard for a Precision Clock Synchronization

Protocol for Networked Measurement and Control Systems

Ingress Protection & Pollution Degree

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Frontal IP30

Rear IP20

Sides IP20

Product safety protection IP20

Pollution Degree II

Environmental Requirements

Test Description Test Levels

IEC 60068-2-1 Cold temperature -40 °C, 16 Hours

IEC 60068-2-2 Dry heat temperature +85 °C, 16 Hours

IEC 60068-2-14 Change of temperature Each cycle of 9-hour, temperature from -40°C to +55°C and 2.5 hours for each steady-state temperature periods.

Test Description Test Levels

60068-2-30 Damp heat temperature, 95%(non-condensing)55 °C cyclic (12 + 12 h cycle)

IEC 60255-21-1 Mechanic vibration 2 g @ (10 - 150) Hz

IEC 60255-21-2 Mechanic shock 15 g @ 11 mS

IEC 60255-21-3 Mechanic Seismic Class 2

Safety Compliance

IEC 60255-5 Insulation Class I

IEC 61010-1

Safety Requirements

IEC 60255-27

EMC Tests (IEC 60255-26) – Comply with IES 61000-4-2, 61000-4-3, 61000-4-4, 61000-4-5, 61000-4-6, 61000-4-8, 61000-4-11, 61000-4-29, 61000-4-17, 61000-4-

18, 60255-26, CISPR11, CISPR22

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3.3 – Supply and install two sets of RF essential kit model KMU-N09-D1-RF, including through hole antenna mount (GE model97-4278A14 or approved equal), 5dB NGP antenna (GE model 97-4278A31 or approved equal), cable connectors, charge guard, surge protector lightening arrestor (GE 97-1680A30 or approved equal, cable jumper (GE 97-1677A159 or approved equal) and any other hardware required to make the radio connection work as a complete system. Make – General Electric or approved equal. Radio link installation must mitigate 25 feet high metallic shed located between 12 KV switchgear and building 247.

4.0 – Supply and install software to monitor, control and record 12 KV circuit breakers, relays and switchgear operations. Make - General Electric, Model – EnerVista Viewpoint Monitoring V8.00 or approved equal with license for five year upgrade. Computer/monitor/speakers shall be supplied by the government, HP Probook 650 G1 with i5 microprocessors with 4GB RAM. Monitoring software shall have following features but not limited to:

1. Capable of monitoring minimum 50 devices / 3000 points

2. Detect connected devices and configure UR devices automatically.

3. Monitor Transformer Protection Equipment - The operating condition of the transformer and the status of the relays are shown through automatically created overview screens. Additional monitoring screens allow further analysis of transformer status by viewing the metering, power, demand, energy and harmonic data that is measured by the associated relay. Monitor critical information such as:

• Transformer energization status

• Real time power quantities (amps, transformer loading, demand)

• Current harmonic analysis

• Accumulated loss of life

• Tap changer position

• Hottest transformer winding temperature

4. Monitor Generator Protection Equipment

Automatically created overview screens provide insight on generator operating conditions and the status of connected relays. Further generator analysis can be performed with additional monitoring screens that monitor the value of metered quantities, the generator temperature monitored by RTD’s and alarms that have been detected by the relay. Additional screens also provide historical information indicating cause of the last generator trip, operating information the relay has learned about the generator and maintenance issues that may need addressing. Monitor critical information such as:

• Generator loading

• Real time power quantities (amps, volts)

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• Cause of trip data

• Generator running hours

• History of generator trips

• Generator temperature

5. Monitor Feeder Protection Equipment

Automatically created overview screens provide insight on feeder operating conditions and the status of connected relays. Additional monitoring screens are available for analyzing metering quantities, along with the power, demand and energy values that may be measured by the relay. If supported by the relay, synchronism screens will also be available for helping to determine if it is safe to close the breaker and energize the feeder. Monitor critical information such as:

• Breaker status

• Accumulated breaker arcing current

• Real time power quantities (amps, volts, demand, energy)

• Synchronism data

6. Monitor Breaker Equipment

Predefined screens allow quick setup and viewing of critical breaker information such as:

• Breaker status

• Number of breaker trip operations

• Real time current, voltage and power levels

6. Power Quality Monitoring - Monitor critical information such as:

• Power quality and equipment status

• Load unbalances using real time and maximum and minimum values

• Consumption and cost of energy using inputs from revenue meters

• Amount of total harmonic distortion on the power system

7. Backup Power Monitoring - Monitor Critical Backup Assets

Monitor critical information such as:

• Availability of normal and emergency power sources

• Status of power source connections

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• Real time voltages and frequency

• Switch status, timer settings and control switch position

• Stored events and exerciser schedules

8. View the Power System Status on Customizable Single-Line Diagrams

Capable to easily create customized single-line diagrams providing monitoring and control. This tool will communicate with supported devices and enable energy system control from either a local or a remote location. Easily Create Customized Single-Line Monitoring Screens

• Create single-line diagrams using user-friendly, drag-and-drop tools with standardized symbols and components representing power system assets (transformers, breakers, CT’s and PT’s)

• Import graphics (bmp, jpg, png) to customize single-line diagrams quickly

• Display power system values and status with minimal configuration through pre-loaded memory maps

• Create customized or “virtual” monitoring points using the powerful Formula Editor

9. Monitor Power System Devices

• Provide a system-wide view of the power system on one single-line monitoring screen

• Analyze the magnitude of critical power quantities measured by devices

• Generate alarm warnings when measured values exceed configurable critical levels

• Create links to multiple monitoring screens to analyze power system equipment with greater detail

10. Control Power System Equipment

• Send commands to devices to control and change the status of power system equipment (breakers, switches, isolators)

• Enforces required two-step verification process to the operator sending the command

• Validates user’s permissions by requiring passwords to be sent to protection relays or other devices before operation occurs

11. Event Logging

The event records from various devices can be automatically downloaded from each device and stored in a centralized, system-wide, sequence of event record. Monitoring program will continually poll each device to see if any new events have been added to that device’s event record. Once a new event

PAGE 17/21

has been detected, the event record will be downloaded and the new events will be stored in the system-wide sequence of events record.

12. Waveform Archiving

The waveform (oscillography) files from various devices can be automatically downloaded from each device and stored on your hard drive. Similar to Event Logging, monitoring program will continually poll each device to see if any new waveform files have been created. Once a new waveform has been detected, the file will be downloaded by Viewpoint Monitoring to the centralized data repository.

13. The Event Viewing

The Event Viewer centrally stores and displays information about preset and configured systems events. Each event in the record contains the following information:

This data can be sorted by any of the fields indicated above.

Event Time

Event Type

Source Name

Source Type

Event Cause

This data can be sorted by any of the fields indicated above.

14. Waveform Viewing

View and analyze waveform fault data that has been recorded from a power system device in a time-based, phasor quantity or tabular view. This Waveform View utility provides functionality to:

• Merge and overlay waveforms that were recorded from multiple devices

• Identify the harmonic content in the monitored parameters

15. Reports

(a) Data Logging

• Log and trend the value of monitored analog or digital points

• Data values are stored in a Microsoft SQL Server Express database

• View logged data for a pre-configured, customized recorded time period

(b) Reports

• Create up to 100 customized records

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• Store up to 50 points per record for 5000 points logged in total

(c)Chart

• View logged data in a pre-configured, customized date range for trending analysis

(d) Archiving Data

• Manually archive recorded data for storage onto network data repositories to reduce risk of data loss and decrease data storage requirements on local workstations

(e)Exporting and Printing Data

• Export data into an Excel format for easy data manipulation and analysis

• Print data that is logged in trending reports

16. Third-Party Device Support

Support communication with third-party devices that utilize Modbus RTU or Modbus TCP/IP, providing a simple way to integrate these devices.

Monitoring program provides support for third-party devices as follows:

(a) Single-Line Diagrams

• Read the status of digital point

• Read the value of analog data

• Send commands to control power system equipment

(b) Annunciator Panel

• Present an alarm when analog value surpasses a preset level or condition

• Present an alarm when a digital point(s) change state

(c) Trending Reports

• Log the value of analog points over prolonged time periods

• Log the status of digital points on a device

17. Annunciator Alarming

Receive Reliable Notification of System Alarms from Devices on the Network

Monitoring program Annunciator Alarming actively monitors measured values and generates alarms. Alarms can be configured to be activated whenever a digital status changes state, or an analog value changes beyond any programmed threshold. Alarms can be delivered through multiple visual, audio, or e-mail notification channels. Furthermore, the Monitoring and Alarm Sentry ensures annunciators and alarms are always active.

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(a) Audio Notification

• Separate sounds for alert status and alarm status

• Audio notification of alarms and alerts continue until the alarm state is acknowledged by an operator

(b)Visual Notification

• Annunciator screen shows the status of the monitored point

• The alarmed point will flash in a color chosen by the user until the alarm is reset by the operator

(c)Email Notification

• Alarming of any monitored point can automatically generate an email to notify users of the alarm

• A different email address can be entered for each monitored point

(d) Monitoring and Alarm Sentry

• Ensures annunciators and alarms are always active, even when the annunciator screens or the Viewpoint Monitoring software is closed in error

(e)Reliable Alarm Notification

• Create alarms on monitored digital and/or analog data points

• Configured alarm warnings delivered through audio, visual or email notification channels

18. Remote Monitoring

(a) Remote Monitoring and Control

• Connect remotely to a Program Monitoring system over a network

-- Connect up to 10 View Nodes to a single Program Monitoring system or

-- Connect up to 4 clients to a single Program Monitoring system using Terminal Services in Microsoft

(b) Microsoft Windows Server 2012

• Implement security access through user accounts with configurable permissions

• Access

-- Plug and Play screens

-- One-Line diagrams

-- Annunciators panels/trending reports

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-- Events

-- Waveforms

19. OPC Server Option

Monitoring program should be able to send the data that is being read from the relays and meters to any third-party OPC compliant automation or monitoring system.

Integrate the data retrieved by Monitoring Program into a larger monitoring or automation system.

• Send up to 65000 data points to an OPC Client

• Supports the entire library of devices

• Provides the ability to send data from third-party devices added to the Monitoring Program database

5.0 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 not 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 shutdown 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.

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11. Contractor shall provide minimum of 16 hours of training to operate, program and maintain all relays. And train to remotely operate, monitor and program relays with computer software.

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

13. 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.

14. All cables and wires outside 12KV switchgear shall be in minimum ¾” EMT conduit.

15. Supply and install wires and conduits to connect all relays, switches, radio transmitters, receivers and any other communication component.

16. All wall and ceiling core drills in 12 KV switchgear building and CGA building 247 to run conduits to antenna shall be weather tight sealed as per the required code.

17. Any damage to existing wall, ceiling, paint, electrical, mechanical or building structure shall be restores o original condition.

18. All operation and maintenance manuals and instructions must be submitted in three sets of CDs and ring binding folders with appropriate tabs.

----- END OF SECTION 01011 -----

SECTION 011400 - WORK RESTRICTIONS

Page 1/3

DIVISION 01 - GENERAL REQUIRMENT

SECTION 011400

WORK RESTRICTIONS

1.1 SUBMITTALS

Government approval is required for submittals with a "G" designation;

submittals not having a "G" designation are for Contractor Quality Control approval. The following shall be submitted in accordance with Section

01330 SUBMITTAL PROCEDURES:

SD-01 Preconstruction Submittals

• Completed Special Access Determination Form; G

1.2 SPECIAL SCHEDULING REQUIREMENTS

1.2.1 The DDJC will remain in operation during the entire construction period.

This facility is in operation 24 hours a day, 6 days a week, year around.

The Contractor shall conduct his operations so as to cause the least possible interference with normal operations at this facility.

1.2.2 Permission to interrupt any roads on this base and/or utility services shall be requested in writing a minimum of 14 calendar days prior to the desired date of interruption.

1.2.3 The work under this contract requires special attention to the scheduling and conduct of the work in connection with existing operations and other projects that may be underway concurrently with this project. Identify on the construction schedule each factor which constitutes a potential interruption to operations or other projects.

1.2.4 Work will be phased to reduce interruption to mission and office functions.

1.3 CONTRACTOR ACCESS AND USE OF PREMISES

1.3.1 Activity Regulations

Ensure that Contractor personnel employed and working on this Defense Depot become familiar with and obey Defense Depot regulations including safety, fire, traffic and security regulations. Keep within the limits of the work and avenues of ingress and egress. To minimize traffic congestion, delivery of materials shall be outside of peak traffic hours (6:30 to 8:00 a.m. and 3:30 to 5:00 p.m.) unless otherwise approved by the Contracting Officer. Wear hard hats in all construction areas and in other designated areas. Do not enter any RESTRICTED areas unless required to do so and until cleared for such entry. The Contractor's equipment shall be conspicuously marked for identification.

1.3.2 Working Hours

Regular working hours shall consist of a 9-hour period established by the Contracting Officer, normally Monday through Friday, 7:00 a.m. to 3:30 p.m., excluding Government holidays.

1.3.3 Work Outside Regular Hours

Work outside regular working hours requires Contracting Officer approval.

Make application 7 calendar days prior to such work to allow arrangements to be made by the Government for inspecting the work in progress, giving

Page 2/3 the specific dates, hours, location, type of work to be performed, contract number and project title. Based on the justification provided, the Contracting Officer may approve work outside regular hours. During periods of darkness, the different parts of the work shall be lighted in a manner approved by the Contracting Officer. Make utility cutovers after normal working hours or on Saturdays, Sundays, and Government holidays unless directed otherwise.

1.3.4 Occupied and Existing Buildings

The Contractor shall be working in existing buildings and around existing buildings which are occupied. The existing buildings and their contents shall be kept secure at all times.

1.3.5 Utility Cutovers and Interruptions

1.3.5.1 Make utility cutovers and interruptions after normal working hours or on Saturdays, Sundays, and Government holidays. Conform to procedures required in the paragraph "Work Outside Regular Hours."

1.3.5.3 Operation of Station Utilities: The Contractor shall be responsible for the operation of control devices in the DDJC utilities system, including water, sewer, electrical, and steam services. The Government will provide supervision and direct which control devices to operate. The Contractor shall not operate control devices except when the COR is present. The Contractor shall notify the Contracting Officer giving reasonable advance notice when such operation is required.

1.4 SECURITY REQUIREMENTS

1.4.1 Personnel and Vehicle Security

1.4.1.1 Commercial Vehicles

Vehicle passes will be issued for both contractor personal vehicles and for each commercial vehicle required for the job, authorizing entry and parking within the DDJC. Every vehicle entering the DDJC will display the pass on the dashboard or visor (facing outward). The pass will be visible at all times while in the DDSP. Parking is limited to those areas that are specifically identified on the pass. If additional passes are required, present adequate justification to the Pass and ID Office via the Contracting Officer.

1.4.1.2 Parking

Do not park on or block the marked fire lanes or crane rail traveling zones (marked in yellow) at any time. An exception may be made for vehicles which are part of the equipment needed to do the required work.

1.4.1.3 Vehicle Searches

Vehicles are subject to search while entering, remaining in, or leaving the Depot. Methods of search include, but are not limited to visual search and search by trained canine.

1.4.1.4 Areas Not Covered by Contract

Page 3/3

Contractor personnel will not be permitted to enter Depot buildings, spaces, and areas not covered by this contract except on prior approval of the Depot department/office/shop having jurisdiction of the areas.

Coordinate action with the Contracting Officer to obtain such entry approval.

Contractor employees will be allowed to use the following DDJC cafeterias during normal hours of operation:

• Building 16 Cafeteria

• Building 100 Cafeteria

1.4.1.5 Identification Badges - comply with the following:

1.4.1.5.1 Submit a Visit Request for each person that will be required to work on-site to the Security Officer via the Contracting Officer at least 1 week prior to the start date. Request forms will be provided by the Contracting Officer or the COR.

1.4.1.5.2 Contract employees and representatives requiring access are U.S.

citizens or legal residents of U.S.

1.4.1.5.3 Under no circumstances shall contractor personnel hand carry their own visit request.

1.4.1.5.4 Contract employees shall provide documented proof of U.S. citizenship or legal residency to the Pass and ID Office prior to being issued a Depot badge.

1.4.1.5.5 Contract employees shall be available for interviews upon request by the Depot Security Specialist.

1.4.1.5.6 Contract employees shall wear and display the Depot badge at all times while entering, remaining in, and exiting Depot spaces and each badge shall be used only by the specific individual named on the badge.

1.4.1.5.7 Maintain strict accountability over identification badges and passes issued by the Pass and ID Office both on and off base. Return badges/passes to the Pass Office immediately upon termination of any employee, expiration, completion of contract, or when no longer required.

1.4.2 Photographs

Photography is prohibited on the Depot. When operationally required, submit a written request containing specific justification and details to the Security Officer via the COR.

PART 2 PRODUCTS

Not used.

PART 3 EXECUTION

Not used.

SECTION 013201 - PROJECT SCHEDULE

Page 1/10

DIVISION 01 GENERAL REQUIREMENTS

SECTION 013201

PROJECT SCHEDULE

PART 1 GENERAL

1.1 REFERENCES

1.2 QUALIFICATIONS

PART 2 PRODUCTS (NOT APPLICABLE)

PART 3 EXECUTION

3.1 GENERAL REQUIREMENTS

3.2 BASIS FOR PAYMENT

3.3 PROJECT SCHEDULE

3.3.1 Use of the Critical Path Method

3.3.2 Level of Detail Required

3.3.2.1 Activity Duration

3.3.2.2 Procurement Activities

3.3.2.3 Government Activities

3.3.2.4 Responsibility

3.3.2.5 Work Areas

3.3.2.6 Modification or Claim Number

3.3.2.7 Bid Item

3.3.2.8 Phase of Work

3.3.2.9 Category of Work

3.3.2.10 Feature of Work

3.3.3 Scheduled Project Completion

3.3.3.1 Project Start Date

3.3.3.2 Constraint of Last Activity

3.3.3.3 Early Project Completion

3.3.4 Interim Completion Dates

3.3.4.1 Start Phase

3.3.4.2 End Phase

3.3.4.3 Phase X

3.3.5 Default Progress Data Disallowed

3.3.6 Out-of-Sequence Progress

3.3.7 Negative Lags

3.4 PROJECT SCHEDULE SUBMISSIONS

3.4.1 Preliminary Project Schedule Submission

3.4.2 Initial Project Schedule Submission

3.4.3 Periodic Schedule Updates

3.4.4 Standard Activity Coding Dictionary

3.5 SUBMISSION REQUIREMENTS

3.5.1 Data Disk

3.5.1.1 File Medium

3.5.1.2 Disk Label

3.5.1.3 File Name

3.5.2 Narrative Report

3.5.3 Approved Changes Verification

3.5.4 Schedule Reports

3.5.4.1 Activity Report

3.5.4.2 Logic Report

3.5.4.3 Total Float Report

3.5.4.4 Earnings Report

3.5.5 Network Diagram

3.5.5.1 Continuous Flow

3.5.5.2 Project Milestone Dates

3.5.5.3 Critical Path

Page 2/10

3.5.5.4 Banding

3.5.5.5 S-Curves

3.6 PERIODIC PROGRESS MEETINGS

3.6.1 Meeting Attendance

3.6.2 Update Submission Following Progress Meeting

3.6.3 Progress Meeting Contents

3.6.3.1 Start and Finish Dates

3.6.3.2 Time Completion

3.6.3.3 Cost Completion

3.6.3.4 Logic Changes

3.6.3.5 Other Changes

3.7 REQUESTS FOR EXTENSIONS

3.7.1 Justification of Delay

3.7.2 Submission Requirements

3.7.2.1 Affected Activities

3.7.2.2 Explanation

3.7.2.3 Analysis

3.7.2.4 Sub-Network

3.7.3 Additional Submission Requirements

3.8 DIRECTED CHANGES

3.9 OWNERSHIP OF FLOAT

Page 3/10

1.1 REFERENCES

The publications listed below form a part of this specification to the extent referenced. The publications are referred to within the text by the basic designation only.

AACE INTERNATIONAL (AACE)

AACE 29R-03 (2011) Forensic Schedule Analysis AACE 52R-06 (2006) Time Impact Analysis - As Applied in Construction

U.S. ARMY CORPS OF ENGINEERS (USACE)

ER 1-1-11 (1995) Administration -- Progress, Schedules, and Network Analysis Systems

1.2 QUALIFICATIONS

The Contractor shall designate an authorized representative who shall be responsible for the preparation of all required…