W912QR25RA023_Specs-0002.pdf

11. THIS ITEM ONLY APPLIES TO AMENDMENTS OF SOLICITATIONS

The above numbered solicitation is amended as set forth in Item 14. The hour and date specified for receipt of Offers is extended. is not extended.

Offers must acknowledge receipt of this amendment prior to the hour and date specified in the solicitation or as amended, by one of the following methods:

(a) By completing items 8 and 15, and returning copies of the amendment; (b) By acknowledging receipt of this amendment on each copy of theoffer submitted;

or (c) By separate letter or electronic communication which includes a reference to the solicitation and amendment numbers. FAILURE OF YOUR ACKNOWLEDGMENT TO BE RECEIVED AT THE PLACE DESIGNATED FOR THE RECEIPT OF OFFERS PRIOR TO THE HOUR AND DATE SPECIFIED MAY RESULT IN REJECTION OF YOUR OFFER.

If by virtue of this amendment you desire to change an offer already submitted, such change may be made by letter or electronic communication, provided each letter or electronic communication makes reference to the solicitation and this amendment, and is received prior to the opening hour and date specified.

12. ACCOUNTING AND APPROPRIATION DATA (If required)

13. THIS ITEM APPLIES ONLY TO MODIFICATIONS OF CONTRACTS/ORDERS.

IT MODIFIES THE CONTRACT/ORDER NUMBER AS DESCRIBED IN ITEM 14.

CHECK ONE A. THIS CHANGE ORDER IS ISSUED PURSUANT TO: (Specify authority) THE CHANGES SET FORTH IN ITEM 14 ARE MADE IN THE CONTRACT ORDER

NUMBER IN ITEM 10A.

B. THE ABOVE NUMBERED CONTRACT/ORDER IS MODIFIED TO REFLECT THE ADMINISTRATIVE CHANGES (such as changes in paying office, appropriation data, etc.) SET FORTH IN ITEM 14, PURSUANT TO THE AUTHORITY OF FAR 43.103(b).

C. THIS SUPPLEMENTAL AGREEMENT IS ENTERED INTO PURSUANT TO AUTHORITY OF:

D. OTHER (Specify type of modification and authority)

E. IMPORTANT: Contractor is not is required to sign this document and return copies to the issuing office.

14. DESCRIPTION OF AMENDMENT/MODIFICATION (Organized by UCF section headings, including solicitation/contract subject matter where feasible.)

Except as provided herein, all terms and conditions of the document referenced in Item 9A or 10A, as heretofore changed, remains unchanged and in full force and effect.

15A. NAME AND TITLE OF SIGNER (Type or print) 16A. NAME AND TITLE OF CONTRACTING OFFICER (Type or print)

15B. CONTRACTOR/OFFEROR

(Signature of person authorized to sign)

15C. DATE SIGNED 16B. UNITED STATES OF AMERICA

(Signature of Contracting Officer)

16C. DATE SIGNED

Previous edition unusable STANDARD FORM 30 (REV. 11/2016) Prescribed by GSA FAR (48 CFR) 53.243

AMENDMENT OF SOLICITATION/MODIFICATION OF CONTRACT 1. CONTRACT ID CODE PAGE OF PAGES

2. AMENDMENT/MODIFICATION NUMBER 3. EFFECTIVE DATE 4. REQUISITION/PURCHASE REQUISITION NUMBER 5. PROJECT NUMBER (If applicable)

6. ISSUED BY CODE 7. ADMINISTERED BY (If other than Item 6) CODE

8. NAME AND ADDRESS OF CONTRACTOR (Number, street, county, State and ZIP Code) (X) 9A. AMENDMENT OF SOLICITATION NUMBER

9B. DATED (SEE ITEM 11)

10A. MODIFICATION OF CONTRACT/ORDER NUMBE

10B. DATED (SEE ITEM 13)

CODE FACILITY CODE

J 1 2

0002 12 MAY 2025 505014

W912QR

W072 ENDIST LOUISVILLE

KO CONTRACTING DIVISION, 600 DR MARTIN LUTHER KING JR PL

LOUISVILLE, KY 40202-2230

UNITED STATES

ALEX HAMILTON, EMAIL: ALEX.J.HAMILTON@USACE.ARMY.MIL

SCD: PAS:

W912QR25RA023

31 MAR 2025

SEE SECTION G - CONTRACT ADMINISTRATION DATA

SEE SCHEDULE

W912QR25RA023_Specs-0002

SECTION SF 30 BLOCK 14 CONTINUATION PAGE

SUMMARY OF CHANGES

SOLICITATION AMENDMENT 0002Block 14 (Description of Amendment/Modification):

Solicitation No. W912QR25RA023 for the Construction of a Microgrid System at Conroe Army Reserve Center (ARC) located in Conroe, TX is hereby amended as follows:

A. The proposal due date has been extended from 14 May 2025 at 2:00 PM ET to 20 May 2025 at 2:00

PM ET.

B. The following PLAN SHEETS have been replaced in their entirety:

G-002 GENERAL LEGEND & GENERAL NOTES

G-106 GENERAL LIFE SAFETY PLAN

B-100 GEOTECHNICAL BORING PLAN

E-005 ELECTRICAL MICROGRID OPERATION DESCRIPTION

ES400 ELECTRICAL ENLARGED PLANS SHEET 1

ES401 ELECTRICAL ENLARGED PLANS SHEET 2

ES402 ELECTRICAL ENLARGED PLANS SHEET 3

ES410 ELECTRICAL SITE LIGHTING PLANS

E-107 ELECTRICAL MICROGRID INTERCONNECTION SWITCHGEAR

ENCLOSURE SECTIONS

E-600 ELECTRICAL MICROGRID INTERCONNECTION SWITCHGEAR ONE-LINE

DIAGRAM

E-621 ELECTRICAL PV SYSTEM WIRING DIAGRAM

S-501 STRUCTURAL DETAILS SHEET 1

C. The following SPECIFICATION SECTIONS have been replaced in their entirety:

25 08 20 MICROGRID CONTROL SYSTEM

26 23 00 LOW-VOLTAGE SWITCHGEAR

26 31 00 FACILITY-SCALE SOLAR PHOTOVOLTAIC (PV) SYSTEMS

D. Offerors must acknowledge all amendments.

E. All other terms and conditions remain unchanged.

P2: 505014, Microgrid Design 750KWDC Conroe ARC Conroe, TX

SECTION TABLE OF CONTENTS

DIVISION 25 - INTEGRATED AUTOMATION

SECTION 25 08 20

MICROGRID CONTROL SYSTEM

05/21

PART 1 GENERAL

1.1 GENERAL REQUIREMENTS

1.2 ENVIRONMENTAL CONDITION REQUIREMENTS

1.3 OPERATION AND FUNCTIONAL REQUIREMENTS

1.4 DISTRIBUTED ENERGY RESOURCES (DER)

1.5 MODES OF OPERATION

1.6 SYSTEM PROTECTION

1.7 SYSTEM INTEGRATION

1.8 REFERENCES

1.9 DEFINITIONS

1.9.1 Alarm Generation

1.9.2 Alarm Handling

1.9.3 Alarm Routing

1.9.4 Control Logic Diagram

1.9.5 Field Point of Connection (FPOC)

1.9.6 Field Control Network

1.9.7 Gateway

1.9.8 Modbus

1.9.9 Monitoring and Control (M&C) Software

1.9.10 Override

1.9.11 Point, Calculated

1.9.12 Point, Network

1.9.13 Algorithm

1.9.14 Analog

1.9.15 Binary

1.9.16 Change-Of-Value (COV)

1.9.17 Control Wiring

1.9.18 Demand

1.9.19 Graphical User Interface (GUI)

1.9.20 Integration

1.9.21 Protocol

1.10 ADMINISTRATIVE REQUIREMENTS

1.10.1 Sequencing

1.10.2 Scheduling

1.11 SUBMITTALS

1.12 SUBMITTAL REQUIREMENTS

1.12.1 Installation Drawings

1.12.2 Shop Drawings

1.12.3 Draft As-Built Drawings

1.12.4 Final As-Built Drawings

1.12.5 Implementation Plan

1.12.6 Microgrid Installation Design Package

1.12.7 Operation and Maintenance (O&M) Instructions

1.12.8 Preventive Maintenance Work Plan

1.12.9 Operational Training Documentation

SECTION 25 08 20 Page 1

AMENDMENT 0002

CERTIFIED FINAL

1.12.10 Maintenance and Configuration Training Documentation

1.12.11 Closeout QC Checklist

1.13 TEST EQUIPMENT

PART 2 PRODUCTS

2.1 MICROGRID CONTROL SYSTEM PRODUCT REQUIREMENTS

2.2 APPLICATION SOFTWARE, OPERATING SYSTEM, AND LICENSES

2.3 MICROGRID CONTROL SYSTEM PRODUCT SPECIFICATION

2.3.1 Real-Time Automation Controller (RTAC)

2.3.2 Modular Input/Output Backplane

2.3.2.1 Operational and Functional Requirements

2.3.2.2 Processor Module

2.3.2.3 Input and Output Modules

2.3.2.4 Security Features

2.3.2.5 Programmable Control

2.3.3 Network Switches

2.3.4 Satellite-Synchronized Network Clock

2.3.5 Rack-Mount Touchscreen Monitor(s)

2.3.6 Rack-Mount USB Keyboard with Integrated Trackball

2.3.7 Control Devices

2.3.8 Control Circuit Wiring

PART 3 EXECUTION

3.1 INSTALLATION

3.2 TESTS, INSPECTIONS, AND VERIFICATIONS

3.3 FACTORY ACCEPTANCE TEST (FAT)

3.4 HARDWARE IN THE LOOP (HIL) TEST

3.5 MICROGRID SYSTEM FIELD TESTING AND COMMISSIONING

3.5.1 Commissioning

3.5.2 General Requirements

3.5.3 Commissioning Overview

3.5.4 Starting and Testing

3.5.5 Witnessing of Starting and Testing

3.5.6 Manufacturer(s) and System Vendor(s) Involvement

3.5.7 Start-Up Documentation

3.5.8 Operation and Maintenance of Equipment and Systems

3.5.9 Test Results

3.5.10 Instruments/Equipment

3.5.11 Commissioning Performance Verification (PV)

3.5.12 Authorities Having Jurisdiction

3.5.13 Checks, Adjustments, and Tuning

3.5.14 Deficiencies, Faults, Defects

3.5.15 Training

3.5.16 Maintenance Materials, Spare Parts, Special Tools

3.5.17 Installed Instrumentation

3.5.18 Performance Verification Tolerances

3.5.19 Owner's Operational Testing

3.5.20 Testing and Commissioning Stages

3.5.20.1 Stage 1 - Contractor's Field Tests

3.5.20.2 Stage 2 - Conditional Acceptance Performance Tests

3.5.20.3 Stage 3 - Acceptance Tests

3.5.20.4 Stage 4 - Endurance Tests

3.5.21 Training

-- End of Section Table of Contents --

SECTION 25 08 20 Page 2

SECTION 25 08 20

MICROGRID CONTROL SYSTEM

05/21

Amendment 0002

PART 1 GENERAL

1.1 GENERAL REQUIREMENTS

This section includes the requirements developed for the microgrid control system (MGCS) which is part of the switchgear detailed in Section 26 23 00

LOW-VOLTAGE SWITCHGEAR.

This section includes general requirements for engineering, design, installation, supervisions, testing and commissioning of the microgrid control system including integration of new and existing Distributed Energy Resources (DER) under the scope of the project. The microgrid control system must perform system protection and control functions in manners to avoid threats to personnel safety, out-of-phase reclosing, and maintaining system stability and power quality. The Microgrid control system (MGCS) functionality for the project must comply with the microgrid control system functionality be as defined by the IEEE 2030.7 and IEEE 2030.8 microgrid controller standards.

The specification and design drawings included as part of tender document form basis of the design and are intended to convey general physical layout, functional and performance requirements of the microgrid control system. The design drawings of the control system do not show all of the required components and all of the power and communication interconnections required to provide a complete, fully integrated, and functional microgrid control system.

Provide the service of a qualified system integration company to develop and advance the design, and produce a complete, fully integrated electrical, control and communication microgrid installation design package for Engineer's review and approval. The design package must be developed based on the actual equipment to be installed and/or existing equipment to be integrated into the microgrid system. The system integrator company must demonstrate that it has successfully completed the development, construction and commissioning of at least three projects involving distributed energy resources with at least 1 MW with a minimum of twelve

(12) months of successful operating history. Please include references from these projects.

The installation shop drawings must include layout/assembly/installation drawings of equipment, components terminal boxes and terminations drawings, schematic diagrams, point-to-point interconnection wirings with cable tags and termination identification for field installation.

Coordinate all activities required to produce the installation shop drawings. Include all equipment and components, system interconnections, configuration, software programming, testing and commissioning necessary to achieve the project objectives, functions and performance requirements specified herein.

SECTION 25 08 20 Page 3

Perform supplemental studies and/or designs- necessary to comply with the requirements of the specification. Submit drawings and engineering data in accordance with the submittal requirements and schedule to assure compliance with the project requirements, overall construction schedule, and the project in service date. Take into considerations economics, safety of operation, acceptable performance, reliability, interchangeability of parts, O&M familiarity, and other benefits.

1.2 ENVIRONMENTAL CONDITION REQUIREMENTS

Microgrid control system equipment temperature, ingress protection ratings, corrosion protection measures, and hazardous area classification ratings must be suitable for the installation environment.

Design room temperature will be 50-80 degrees F with relative humidity (RH) in the range of 10 percent to 90 percent non-condensing. Outside air requirements will be based on ASHRAE 62.1 and/or ICC IMC . Cooling and heating loads, as performed by the switchgear provider, will be required to be calculated using weather data for the project location.

1.3 OPERATION AND FUNCTIONAL REQUIREMENTS

Operating the Microgrid system in parallel with the Electrical Power System (EPS).

Separating from and operating the Microgrid system in island mode intentionally or unintentionally.

Connecting the microgrid system back to parallel operation with the EPS when service condition is restored normal.

Dispatching and controlling Distributed Energy Resources (DER) that are part of microgrid control integration. The microgrid control system must have the capability to interface with the DER control system to allow dispatching, controlling, and disconnecting of the DER including initiate automatic synchronization, control mode of operation, power output control, source transfer and load transfer scheme, and prohibit unsynchronized sources tie-in.

Provide for reliable, fast, secure and real-time communication.

Communication architecture, control hierarchy, data transmission requirements in terms of rate, delay (or latency), and reliability are to comply with specific functions necessary to accomplish a proper operation of the microgrid. The IEC 61850 standard (protocol used in digital substation systems and smart distribution systems) must be used as the standard communication protocol for the project.

1.4 DISTRIBUTED ENERGY RESOURCES (DER)

The following Distributed Energy Resources (DER) must be incorporated as part of the project microgrid system:

a. A car port roof-mounted solar photovoltaic (PV) system. The PV System will provide energy into the microgrid system whenever the solar energy is available.

b. Two (2) natural gas generator units that have the primary function of providing backup power during utility outages.

SECTION 25 08 20 Page 4

AMENDMENT 0002

1.5 MODES OF OPERATION

There are three states (or Modes of Operation) of a microgrid power system: Grid Connected, Islanded, and Blackout state of conditions. The Grid Connected and the Islanded modes are the two working modes of operations where the microgrid power system is energized. In Blackout mode, the power system is completely deenergized. See Design Drawing for Microgrid's Mode of Operation Diagram and description.

1.6 SYSTEM PROTECTION

The microgrid control system must incorporate protection system components and schemes to detect defective power system elements or conditions of an abnormal or dangerous nature, to initiate the appropriate control circuit action, and to isolate the appropriate system components.

The microgrid control system must incorporate system control and protection schemes in such manners to avoid threats to personnel safety, prevent or minimize equipment damage, maintaining dynamic stability and power quality, and minimize the system outage area.

The microgrid system protection scheme achieves voltage and frequency ride through characteristics per the requirement of the IEEE 1547 standard at

POI.

For all POI synchronization check (25) functionality must be provided to prevent unintentional out-of-synchronize closing generation sources.

Reconnection of generator source(s) must be performed through an automatic synchronizer (25A). The IEEE C50.12 and IEEE C50.13 provide recommendation of synchronous generator synchronization settings used in a POI relay.

1.7 SYSTEM INTEGRATION

Microgrid System Integrator - Designate an individual (such as the Microgrid Protection and Control System Supplier) to act as the Project's System Integrator Lead. Coordinate the microgrid control system integration including:

a. Assemble a qualified system integration team.

b. Coordinate with Owner, Engineers, and equipment manufacturers in determining operational and maintenance requirements and system performance requirements that will have impact on how the microgrid system is integrated and implemented.

c. Advance the development of microgrid operating philosophy, control and protection scheme.

d. Facilitate development of final sequence of operations, system configuration, and programming specific to the project site operational requirements.

e. Coordinate with Owner, Engineers, and equipment manufacturers in determining the specific power, control and communication interface equipment, hardware, software and interconnection requirements between Microgrid control system and associated system components.

f. Determine, develop and optimize communication architecture, control hierarchy, data transmission requirements and select appropriate

SECTION 25 08 20 Page 5 control and communication media and equipment.

g. Develop microgrid implementation plan.

h. System Integrator will serve as a single point of contact responsible for microgrid system integration prior to, during the construction and warranty period, and must be available for consultation during all phases of the project. Further requirements for commissioning are defined in Section 01 46 00.00 07 COMMISSIONING - MICROGRID for the MicroGrid Integration Commissioning specialist.

i. Microgrid Systems Integrator must be present at factory acceptance testing and on site and directing all testing and commissioning of the microgrid control system.

j. Submit the qualifications of the Microgrid Systems Integrator as part of the proposal. Provide documents that substantiate the qualifications of the proposed individual with the following minimum requirements:

(1) Licensed Professional Electrical Engineer, Control Systems Engineer, or Computer Systems Engineer.

(2) Minimum of fifteen (15) years experiences with at least five (5) years in control system integration practice.

(3) Past experience with similar projects within the past ten (10) years.

The Owner will review the qualifications of the Microgrid System Integrator before the Contractor brings the microgrid system integrator onboard to the team.

1.8 REFERENCES

Electrical systems must be engineered, manufactured and installed in accordance with the National Electrical Codes. The design and engineering of the electrical installation must satisfy all statutory requirements of the national and/or local authorities. The electrical installation must be suitable for the site conditions as specified. Where necessary, special attention must be paid to the selection and installation of electrical equipment suitable for seismic conditions. Where relevant, the specific publications are referenced herein.

The following reference standards documents form part of the specification to the extent stated. Where differences exist between codes and standards, the one affording the greatest protection must apply. Unless otherwise noted, the referenced standard edition is the current one at the time of commencement of the work.

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.

AMERICAN SOCIETY OF HEATING, REFRIGERATING AND AIR-CONDITIONING

ENGINEERS (ASHRAE)

ASHRAE 62.1 (2019) Ventilation for Acceptable Indoor Air Quality

SECTION 25 08 20 Page 6

INSTITUTE OF ELECTRICAL AND ELECTRONICS ENGINEERS (IEEE)

IEEE 81 (2012) Guide for Measuring Earth Resistivity, Ground Impedance, and Earth Surface Potentials of a Ground System

IEEE 1547 (2018) Interconnection and Interoperability of Distributed Energy Resources with Associated Electric Power Systems Interfaces

IEEE 1613 (2009) Standard Environmental and Testing Requirements for Communications Networking Devices in Electric Power Substations

IEEE 2030.7 (2017) Standard for the Specification of Microgrid Controllers

IEEE 2030.8 (2018) Standard for the Specification of Microgrid Controllers

IEEE C37.90.1 (2013) Standard for Surge Withstand Capability (SWC) Tests for Relays and Relay Systems Associated with Electric Power Apparatus

IEEE C37.118 (2021) Standard for Synchrophasor Measurements for Power Systems

IEEE C37.238 (2017) Standard Profile for Use of IEEE 1588 Precision Time Protocol in Power System Applications

IEEE C50.12 (2005; R 2010) Standard for Salient Pole 50 HZ and 60 Hz Synchronous Generators and Generation/Motors for Hydraulic Turbine Applications Rated 5 MVA and above

INTERNATIONAL CODE COUNCIL (ICC)

ICC IMC (2018) International Mechanical Code

INTERNATIONAL ELECTRICAL TESTING ASSOCIATION (NETA)

NETA ATS (2021) Standard for Acceptance Testing Specifications for Electrical Power Equipment and Systems

INTERNATIONAL ELECTROTECHNICAL COMMISSION (IEC)

IEC 60255 (2022) Measuring Relays and Protection Equipment - Part 1: Common Requirements

IEC 60255-21-1 (1988) Electrical Relays - Part 21:

Vibration, Shock, Bump and Seismic Tests On Measuring Relays and Protection Equipment - Section One: Vibration Tests (Sinusoidal)

SECTION 25 08 20 Page 7

IEC 60255-21-2 (1988) Electrical Relays - Part 21:

Vibration, Shock, Bump and Seismic Tests On Measuring Relays and Protection Equipment - Section Two: Shock and Bump Tests

IEC 60255-21-3 (1993; ED 1.0) Electrical Relays - Part 21: Vibration, Shock, Bump And Seismic Tests On Measuring Relays And Protection Equipment - Section 3: Seismic Tests

IEC 60255-26 (2013) Measuring Relays and Protectyion Equipment - Part 26: Electromagnetic Compatibility Requirements

IEC 60870-5-101 (2003-02) Telecontrol Equipment and Systems – Part 5-101: Transmission Protocols – Companion Standard for Basic Telecontrol Tasks

IEC 60870-5-104 (2006-06) Telecontrol Equipment and Systems – Part 5-101: Transmission Protocols – Companion Standard for Basic Telecontrol Tasks

IEC 61000-4-2 (2008) Electromagnetic Compatibility (EMC)

- Part 4-2: Testing and Measurement Techniques - Electrostatic Discharge Immunity Test

IEC 61000-4-4 (2012) Electromagnetic Compatibility (EMC)

- Part 4-4: Testing and Measurement Techniques - Electrical Fast Transient/Bust Immunity Test

IEC 61131-3 (2013) Programmable Controllers - Part 3:

Programming Languages

IEC 61850 (2021) Communication networks and systems for power utility automation

TELECOMMUNICATIONS INDUSTRY ASSOCIATION (TIA)

TIA-232 (1997f; R 2012) Interface Between Data Terminal Equipment and Data Circuit-Terminating Equipment Employing Serial Binary Data Interchange

TIA-485 (1998a; R 2012) Electrical Characteristics of Generators and Receivers for Use in Balanced Digital Multipoint Systems

1.9 DEFINITIONS

The following list of definitions may contain terms not found elsewhere in this Section but are included here for completeness. Some terms are followed with a protocol reference in parenthesis indicating to which protocol the term and definition applies. Inclusion of protocol-specific

SECTION 25 08 20 Page 8 definitions does not create a requirement to support that protocol, nor does it relax any requirements to support specific protocols as indicated e in this section.

1.9.1 Alarm Generation

The process of comparing a point value (the point being alarmed) with a pre-defined alarm condition (e.g. a High Limit) and performing some action based on the result of the comparison.

1.9.2 Alarm Handling

See paragraph ALARM ROUTING.

1.9.3 Alarm Routing

Alarm routing is M&C software functionality that starts with a notification that an alarm exists (typically as the output of an Alarm Generation process) and sends a specific message to a specific alarm recipient or device.

1.9.4 Control Logic Diagram

A graphicsl representation of control logic for multiple processes that make up a system.

1.9.5 Field Point of Connection (FPOC)

The FPOC is part of the UMCS IP network and acts as the point of connection between the UMCS IP Network and the field control IP network.

The FPOC is an IT device such as a switch, IP router, or firewall, typically managed by the site IT staff. (Note that the field control IP network may consist of a single IP device, or that integration may require installation of a field control network IP device.)

1.9.6 Field Control Network

The network used by a field control system.

1.9.7 Gateway

A device that translates from one protocol to another. Devices that change only the transport mechanism of the protocol - "translating" from LonWorks over TP/FT-10 to LonWorks over IP for example - are not gateways as the underlying protocol (data format) does not change. Gateways are also called Communications Bridges or Protocol Translators.

1.9.8 Modbus

A basic protocol for control network communications generally used in utility control systems. The Modbus protocol standard is maintained by The Modbus Organization.

1.9.9 Monitoring and Control (M&C) Software

The UMCS 'front end' software which performs supervisory functions such as alarm handling, scheduling and data logging and provides a user interface for monitoring the system and configuring these functions.

SECTION 25 08 20 Page 9

1.9.10 Override

To change the value of a point outside of the normal sequence of operation where this change has priority over the sequence. An override can be accomplished in one of two ways: the point itself may be Commandable and written to with a priority or there may be a separate point on the controller for the express purpose of implementing the override.

1.9.11 Point, Calculated

A value within the M&C Software that is not a network point but has been calculated by logic within the software based on the value of network points or other calculated points. Calculated points are sometimes called virtual points or internal points.

1.9.12 Point, Network

A value that the M&C Software reads from or writes to a field control network.

1.9.13 Algorithm

A set of well-defined rules or procedures for solving a problem or providing an output from a specific set of inputs.

1.9.14 Analog

A signal that can take on continuous (as opposed to discrete) values.

Sensors (e.g. temperature, pressure, flow) typically provide analog signals as outputs to represent the measured variable. Within the UMCS, analog signals are generally represented by either 0-10 volt or a 4-20 milliamp signal.

1.9.15 Binary

A two-state system where an "ON" condition is represented by a high signal level and an "OFF" condition is represented by a low signal level.

"Digital" is sometimes used interchangeably with "binary".

1.9.16 Change-Of-Value (COV)

A type of data transmission over the network where the point value is transmitted over the network only when its value changes. COV is an efficient use of network bandwidth.

1.9.17 Control Wiring

This includes conduit, wire, and wiring devices to install complete HVAC control systems, including motor control circuits, interlocks, sensors, PE and EP switches, and like devices. This also includes all wiring from node to node, and nodes to all sensors and points defined in the I/O summary shown on drawings or specified herein, and required to execute the sequence of operation. Does not include line voltage power wiring.

1.9.18 Demand

The maximum rate of use of electrical energy averaged over a specific interval of time, usually expressed in kW.

SECTION 25 08 20 Page 10

1.9.19 Graphical User Interface (GUI)

Human-machine interfacing allows the operator to manage, command, monitor, and program the system.

1.9.20 Integration

Establishing communication between two or more systems to create a single system.

1.9.21 Protocol

In control systems, "protocol" is generally shorthand for "communication protocol"; a defined method by which digital information is exchanged electronically. Often more than one protocol is used in a BAS, for example, a typical BACnet system will use at a minimum (in addition to BACnet/IP and BACnet MS/TP) IP, UDP, ARP, Ethernet, and RS-485 protocols (and this does not include any protocols used internally in the front end or for communication with front end client workstations).

1.10 ADMINISTRATIVE REQUIREMENTS

1.10.1 Sequencing

Performance Verification Testing required by this Section must be proceeded by successful and accepted "contractors field testing" or "start-up and start-up testing" of the control system to be tested.

1.10.2 Scheduling

Coordinate testing schedules with the Government and with work in other Sections performed on the components or systems to be tested.

1.11 SUBMITTALS

Government approval is required for submittals with a "G" or "S" classification. Submittals not having a "G" or "S" classification are for information only. When used, a code following the "G" classification identifies the office that will review the submittal for the Government.

Submit the following in accordance with Section 01 33 00 SUBMITTAL

PROCEDURES:

SD-02 Shop Drawings

Manufacturer Data; G-DO-AE

Manufacturer's Instruction; G-DO-AE

Draft As-Built Drawings; G-DO

Installation Drawings - electrical system interconnection diagrams and schedules; G-DO-AE

Point to Point Wiring Diagrams; G-DO-AE

Bills Of Material; G-DO-AE

Final As-Built Drawings; G-DO

SECTION 25 08 20 Page 11

Implementation Plan; G-DO-AE

SD-05 Design Data

Microgrid Installation Design Package; G-DO-AE

SD-06 Test Reports

Factory Acceptance Test Reports; G-DO-AE

Hardware in the Loop Test Report; G-DO-AE

Manufacturer's Field Test Reports; G-DO-AE

Test Instrumentation Calibration Certificates; G-DO

SD-07 Certificates

UL certification for applicable equipment and material.

Certificate of acceptance from authority having jurisdiction upon completion of Work to Owner Representative.

Test Instrumentation Calibration Certificates

SD-10 Operation and Maintenance Data

Operation and Maintenance (O&M) Instructions; G-DO

Preventive Maintenance Work Plan; G-DO

Operational Training Documentation; G-DO

Maintenance and Configuration Training Documentation; G-DO

SD-11 Closeout Submittals

Closeout QC Checklist; G-DO

1.12 SUBMITTAL REQUIREMENTS

1.12.1 Installation Drawings

All Installation Drawings must conform to the following:

a. Manufacturer's Literatures - The submittal information must have annotation of project's equipment identification (name and/or tags) on their respective sheets. Where equipment vendor's standard product data sheets and/or drawings are furnished which cover a number of variations of the general class of equipment, the information must be annotated to indicate exactly which equipment, parts, and/or accessories are being furnished. Technical data such as equipment ratings, operation parameters, performance data must be provided for each specific piece of electrical equipment as specified.

b. General Arrangement Drawings - The general arrangement (GA) drawings must indicate the physical and electrical limits of the microgrid(s) and all associated point of interconnections including site physical map showing site electrical distribution system; and locations of

SECTION 25 08 20 Page 12

POIs, controllable switches, switchgear, and other equipment that are part of the project microgrid. The drawing will delineate between new system and existing system.

c. Physical Dimensioned Drawings - Provide physical dimensioned drawings for electric service equipment including but not limited to:

switchgear, control panels, operator control console, etc. Outline drawings must depict graphically and dimensionally the configurations, profile, and limitations of parts and assemblies.

d. Wiring Diagrams - Provide applicable one-line, three-line and schematic diagrams to shows wirings, connections and interconnections of the electrical system installation, equipment or its component devices and parts. Drawings must provide such detail as is necessary to be able to trace the electrical circuits and connections involved.

The drawings must include cable numbers, conductor colors, pair/triad numbers, terminal source and designation identifications. If cables are shielded, the shields must be shown on the drawings. All spare conductors must be shown on the drawings.

e. Point to Point Wiring Diagrams - Provide applicable wiring diagrams showing line by line connections of wiring at both ends. Drawings must include cable numbers, conductor identification by color or number. Show cable shielding and number of spares on the drawings.

1.12.2 Shop Drawings

Submit copies of vendor, producer or manufacturer data for materials, devices and subsystems or standard or proprietary products. Include design and installation shop drawings, catalog cuts, specifications, testing requirements, and installation instructions for the following items, but not excluding other items or materials not specifically mentioned herein.

Submit manufacturer's instructions, printed product literature and product data including at a minimum, product characteristics, performance criteria, physical size, weights, arrangements of components, type of material used, type and characteristics of used electrical devices and the minimum space for the erection and maintenance.

System integration and/or engineered system shop drawings must be stamped and signed by registered professional engineer. Equipment shop drawings are not required to be stamped and signed by professional engineer but must have applicable equipment certification and/or label.

Prepare and submit installation shop drawings showing complete microgrid system interconnection and integration for Engineer's review and approval.

The installation shop drawings must include layout, assembly, and installation drawings of equipment, components terminal boxes and terminations drawings, schematic diagrams, point-to-point interconnection wirings with cable tags and termination identification for field installation.

Identify any constructability issues or conflicts between manufacturers' shop drawings and contract documents (drawings and specification) during the Contractor shop drawing review and installation drawing development process. Identify variations between Contract Documents and product or system limitations or functionality that may be detrimental to the successful performance or operation of the completed work. Submit

SECTION 25 08 20 Page 13 proposed resolutions for review and approval by the Engineer.

Comprehensive Bills of Material must be included for each of the proposed major items of equipment and systems and sub-systems.

Complete assembly and installation drawings must be furnished. These drawings must clearly indicate how the work is to be performed in the field including requirements for operation and maintenance access and as required by applicable codes.

Submit electronic copies of all required shop drawings, unless otherwise directed, that include shop, assembly, installation, schematic and wiring Drawings. Drawings must be prepared for all electrical power, control and communication systems and must describe in physical, functional, schematic and wiring terminologies the proposed systems.

1.12.3 Draft As-Built Drawings

Draft As-Built Drawings as a single complete package: electronic drawings in PDF format for review before final set is issued.

1.12.4 Final As-Built Drawings

Final As-Built Drawings as a single complete package: 4 hard copies and 4 digital copies on CDROM. Submit hardcopy drawings on ISO A1 34 by 22 inches and A3 17 by 11 inches sheets, and electronic drawings in both PDF and AutoCAD format.

1.12.5 Implementation Plan

Operational Philosophy including explanation of modes and sequences of operation.

1.12.6 Microgrid Installation Design Package

Microgrid implementation documentation including implementation plan, operating philosophy, mode of operations, sequence of operation for each mode of operation and operating scenarios.

1.12.7 Operation and Maintenance (O&M) Instructions

Four bound O&M Instructions and 4 copies of the O&M Instructions in PDF format on optical disc. Index and tab bound instructions. Submit instructions in PDF form as a single PDF file with a PDF file table of contents containing links to the other files. O&M Instructions may be submitted as a Technical Data Package.

1.12.8 Preventive Maintenance Work Plan

Four copies of the Preventive Maintenance Work Plan. The Preventive Maintenance Work Plan may be submitted as a Technical Data Package.

1.12.9 Operational Training Documentation

Training manuals for Basic Training delivered for each trainee on the Course Attendance List with two additional copies delivered for archival at the project site. Submit two copies of the Course Attendance List with the archival copies. The Basic Training Documentation may be submitted as a Technical Data Package.

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1.12.10 Maintenance and Configuration Training Documentation

One set of training manuals delivered for each trainee on the Course Attendance List with two additional copies delivered for archival at the project site. Submit two copies of the Course Attendance List with the archival copies. The Advanced Training Documentation may be submitted as a Technical Data Package.

1.12.11 Closeout QC Checklist

Submit four copies of the Closeout QC Checklist.

Provide printout documentation of programming logic, system configuration, and parameter settings as implemented for all equipment requiring programming, configuration setup, and parameter settings organized by DER system and by specific equipment.

1.13 TEST EQUIPMENT

Provide all test equipment unless otherwise noted in the contract documents. Use only test equipment with current calibration traceable to the National Institute of Science and Technology (NIST). For each test instrument, submit Test Instrumentation Calibration Certificates demonstrating calibration traceable to NIST. Use test equipment and test methods such that the overall accuracy of the test method, including all test instrumentation and any errors inherent in the test procedure, is at least 50 percent better than the accuracy specified for the sensor. For example, if a temperature sensor has an accuracy requirement of plus or minus 1 degree Farenheit degree overall accuracy of the test method, must be 0.5 degree Farenheit or better.

When validating sensor accuracy, the test instrument is treated as if it is perfectly accurate; that is, the measured value from the test instrument must lie within the bounds of the specified accuracy of the sensor. Expressed mathematically:

Given:

Sensor accuracy: Plus or minus X Sensor reading: Y Test equipment reading: Z Where X, Y and Z are real numberts.

Then Sensor passes if: (Y-X) <= Z <= (Y+X) otherwise, sensor fails

PART 2 PRODUCTS

Equipment indicated by manufacturer, brand name and/or by model number or other specific identification are intended to form the basis of the design. Equipment by other manufacturer may be acceptable provided that it meets the contract requirements and that it is equal in function, performance, quality and other salient features. The contract must provide document showing clear evidence by comparison of equal in function, performance, quality and salient features of substitutions of equal named products by other manufacturers. Equivalent item manufactured by another manufacturer, subject to approval by the engineer with the understanding that all design and/or method of installation changes

SECTION 25 08 20 Page 15 required by the substitution must be made by the Contractor at no additional cost to the contract.

Amendment 0002************************************************************

2.1 MICROGRID CONTROL SYSTEM PRODUCT REQUIREMENTS

The microgrid controller and system protection will comply with IEEE 1547 , IEEE 2030.7 and IEEE 2030.8 and meets the functional requirements specific to microgrids. The microgrid control system will consist of one real time automation controller, DER control interface terminal units, a local human-machine interface (HMI) computer station, one network switch, network security gateway, satellite-synchronized network clock, and protective relay system. The control system network architecture will be configured to provide a robust and reliable data communication network via loop communication links between the microgrid control system components.

Microgrid controller (MGC) - The MGC serve as a centralized command, control, and communication for the microgrid power system. The MGC provides functional control and monitoring of the microgrid electrical distribution system and the DERs in accordance with the programmed interoperability principles for interactive relationships among the various system components. The MGC runs powerful algorithms to monitor electrical loads, DERs capacity and power production, the electrical distribution system operating parameters and execute command and control functions including disconnection and reconnection of microgrid to the utility grid, dispatch of DERs, active and reactive power sharing, peak shaving, maintaining system voltage and frequency stability in island mode, and the black-start sequence. A touch screen human-machine interface (HMI) will be provided for controlling and monitoring microgrid power system including mode of operations, control parameters adjustments, motoring of real-time data, manage alarms, track critical parameter trends, event logs, and reporting.

DMZ Router - One switch is used to provide the interface with the DERs communicating all necessary commands, control and monitoring data between the DERs local controller to the MGC.

************************************************************Amendment 0002

2.2 APPLICATION SOFTWARE, OPERATING SYSTEM, AND LICENSES

Provide all the required software packages with the relevant licenses, programming, and system configurations necessary to implement the microgrid system protection and control functions as described in the project specification.

The licenses must not have restriction concerning the number of signals that can be managed. Neither partial licenses (like database licenses with limitation on record number configuration) nor fixed deadline licenses are acceptable.

All system configuration and application developed for project application must be provided both in compiled and in source version, in order to allow any modification and reload by the Owner/Contractor.

The source files must be properly commented during the implementation to allow a complete understanding by the operation and maintenance staff.

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Detailed operating instruction for programming and configuration must be supplied by the Vendor.

Standard software license must be assigned to Owner for software provided upon initial installation of each software component. Software licenses must be issued in Owner's name and transferred without restrictions to Owner upon completion of Project.

Extend to Owner all rights of software purchased including telephone support during warranty period must be extended to the Owner.

Complete software and programming backup package must be provided by Vendor at the end of the project.

2.3 MICROGRID CONTROL SYSTEM PRODUCT SPECIFICATION

2.3.1 Real-Time Automation Controller (RTAC)

The device must operate as a computer with network access to provide a combination of functions including, but not limited to, visualization and control of process equipment, data aggregation, simultaneous collection of data from serial and Ethernet server devices, and simultaneous data access for multiple client devices. The device must conform to various industry standards, operate in harsh environments, and provide the operational and functional requirements as described below.

The RTAC system must operate simultaneously on multiple serial and Ethernet communications networks. It must provide a combination of functions that include digital input and digital output support, deterministic logic processing, automatic transmission of outgoing messages and processing of responses, data scaling, data aggregation, simultaneous collection of data from multiple server devices, and simultaneous data access for multiple client (master) devices.

a. Power Supply. The device must be available with dual modular hot-swappable power supplies capable of load sharing and operating concurrently among independent power sources on a wide range of both ac and dc input power source voltages: 120/240 Vac.

b. Temperature. The device must be capable of continuous operation over a temperature range of -40 degrees F to +120 degrees F.

c. Environmental Testing. The device must be tested to the same standards as protective relays including IEC 60255-21-1 , IEC 60255-21-2 , IEC 60255-21-3 , IEC 60255-26 , IEC 61000-4-2 , IEC 61000-4-4 , and

IEEE C37.90.1 .

d. Communications Ports. The device must come standard with a minimum of two USB ports, two serial ports, and two rear-panel Ethernet ports.

Each standard serial port must be TIA-232 , BIOS selectable for +5 Vdc port power and capable of operation at 300-115200 bps. Ethernet ports must be independent 10/100/1000 Mbps.

e. Hot-Swappable Industrial Solid-State Drives. The device must have high quality, industrial-temperature rated hard drives. All drives must support hot-swapping.

f. Configuration. Configuration of messages and data processing functions must be through a simple GUI interface. Configuration

SECTION 25 08 20 Page 17 interface must be through local keyboard, mouse, and monitor port.

g. Alarm Output. There must be an alarm contact output to signal internal errors and malfunctions. The alarm contact must be supervised by an internal watchdog system that independently monitors the operating system.

h. Operating System. The device must support at least one of the following operating systems: Microsoft® Windows® 7, Windows 8/8.1, Windows 10, Windows Server® 2008 R2, Windows Server 2012 R2, CentOS Linux® 6, CentOS Linux 7, Red Hat® Enterprise Linux 6, Red Hat Enterprise Linux 7, and VMware® ESXi™ 5.x.

i. Nonvolatile Storage. There must be flash memory used as nonvolatile storage of settings, configuration, and incoming and calculated data within the RTAC. Data stored in the nonvolatile memory must be available for retrieval after sustained power outage, including failure of the internal battery.

j. Manufacturer. The device must be manufactured in the United States.

k. Warranty. The device must include a ten-year warranty for all material and workmanship defects.

2.3.2 Modular Input/Output Backplane

The BackPlane must be dependable, ultra-rugged and designed for harsh environments in a fully integrated, flexible platform.

The microprocessor-based controller system must have the following general features:

a. Real-Time Automation Controller (RTAC) provides high-speed, deterministic control and performance.

b. Modular design supports custom configuration mix of analog and digital I/O options.

c. Provide a 10-slot chassis for large I/O control and monitoring applications.

d. Hardware and components meet or exceed IEEE 1613 specifications for harsh conditions.

e. A whitelist antivirus technology that allows only authorized applications to run.

2.3.2.1 Operational and Functional Requirements

a. Protocols. The information processor must provide the following protocols:

(1) Server: SES-92, FTP, SFTP

(2) Client: CP2179, ASCII and Binary, SNMP

b. Client/Server: DNP3 serial, DNP3 LAN/WAN, IEC 61850 MMS, Modbus® RTU, Modbus TCP, LG 8979, IEEE C37.118 , IEC 60870-5-101 / IEC 60870-5-104

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c. Peer-to-Peer: IEC 61850 GOOSE transmit and receive messages, Parallel Redundancy Protocol

d. Digital Inputs Sequential Events. The system must maintain a user-configurable record of digital input operations on the EtherCAT network that is accurate to 1 ms.

e. DC Analog Inputs. The system can include as many as 16 DC analog input modules.

f. DC Analog Outputs. The system can include as many as 16 DC analog output modules.

g. DC Analog Outputs. The system can include as many as 16 DC analog output modules.

h. AC Protection Inputs. The system can include as many as 16 CT/PT protection modules.

i. Intelligent and Secure Components. All electronic equipment must continuously self-test and report internal errors. The system must have a hardwire contact indicating system health.

j. IEC 61131-3 Programming. The system must include an integrated IEC 61131-3 programming environment, with the ability to monitor and control every connected EtherCAT I/O module, protective relay, and other serial or Ethernet-based intelligent electronic devices (IED) continuously. The IEC 61131-3 programming environment must be integrated in one software package with the communications protocol mapping environment.

k. Role-Based Security. The system must incorporate independent user-based security with strong passwords, role-based accounts, and settable account expirations dates. The system must provide a mechanism to map security related system tags into SCADA reports.

l. Redundant Power Supply Operation. The system must allow the use of two power supply modules that continuously share load. If the incoming power for one module becomes unavailable, the remaining power supply must have sufficient capacity to accommodate an entire node.

m. High-Speed Peer-to-Peer Communication. The system must use IEC 61850 GOOSE protocol to transmit and receive high-speed digital data to/from IEDs to create custom protection and control schemes. IEC 61850 GOOSE must be an available option for the system.

n. IEC 61850 . The information processor must have an option to support IEC 61850 GOOSE transmit and receive messaging. There must also be an option to support IEC 61850 MMS client/server for polling and sending data sets and reports from IEDs.

o. Serial Communications Ports. The system must have four serial ports that must be software configurable for TIA-232 or TIA-485 communications modes. Each serial port connector must have an available demodulated IRIG-B time-synchronization signal.

p. Ethernet Communications Ports. The CPU module for the system must have two Ethernet ports that can operate simultaneously on different networks through independent MAC addresses.

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q. Alarm Output. There must be an alarm contact output to signal internal errors and malfunctions. The alarm contact must be programmable so that the alarm conditions that activate the output can include additional conditions.

r. Environmental Testing. All system modules must be tested to IEEE 1613 for communications and networking equipment in electric power substations. The system modules must also be tested to the same standards as those used for protective relays.

s. Retained Memory. The system CPU must have nonvolatile memory available for user-programmable retained variables.

t. Engineering Access. The system CPU must have methods to create transparent connections between any two serial or Ethernet communications ports for engineering access.

u. Reliability. The vendor must supply the actual measured mean time between failures (MTBF) for the device upon request.

v. Service. The device must include no-cost technical support for the life of the product.

w. Manufacturer. The device must be manufactured in the…