W9123826RA016 Microgrid Amendment 0003.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.

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 1 207

0003 NA

W91238

W075 ENDIST SAN FRAN

KO CONTRACTING DIVISION, 450 GOLDEN GATE AVENUE

SAN FRANCISCO, CA 94102-3406

UNITED STATES

NAIRI FREEMAN, EMAIL: NAIRI.FREEMAN@USACE.ARMY.MIL, TELEPHONE:

(415) 503-6574

SCD: PAS:

W9123826RA016

28 MAY 2026

SEE SECTION G - CONTRACT ADMINISTRATION DATA

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

The purpose of Amendment 0003 is to update specs as stated in the summary of changes on Page 2. The RFI Set #3 is posted concurrently with Amendment 0003.

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.

17 JULY 2026

AMENDMENT #3

Summary of Changes

The following SOLICITATION SHEETS have been edited:

o E-620 ELECTRICAL PV SYSTEMS ONE-LINE AND SCHEMATIC DIAGRAM o REMOVE NOTE 2 o ES406 ELECTRICAL ENLARGED SITE PLANS o SHOW LOCATION OF PANELS MDP1, MDP-STO, MDP-OMS, MDP2 o ES101 ELECTRICAL OVERALL SITE PLAN o INDICATE LOCATION OF ROOM 1099 AND PANELS MDP1, MDP-STO, MDP-OMS, MDP2 o E-600 ELECTRICAL OVERALL ONE-LINE DIAGRAM o INDICATE PV TRANSFORMER AS KNAN/KNAF

The following PLAN SHEETS have been added in their entirety:

The following SPECIFICATION SECTIONS have been replaced in their entirety:

o 26 37 13 MICROGRID CONTROL SYSTEM o 28 31 70 INTERIOR FIRE ALARM SYSTEM, ADDRESSABLE o 25 05 11 CYBERSECURITY FOR FACILITY-RELATED CONTROL SYSTEMS

• CLARIFY REFERENCE TO SECTION 25 05 11.

The following SPECIFICATION SECTIONS have been added in their entirety:

o 01 11 00 GENERAL REQUIREMENTS

• Clarify reference to section 01 11 00 paragraph 1.2.1 to include:

“The campus site has a minimum load of approximately 150kW, an average load of approximately 300kW, and a peak of around 600kW.”

The following PLAN SHEETS have been replaced in their entirety:

o SF1442 edited typo from "kW" to "kWH" o SF1442 corrects due date to July 31, 2026

The following ATTACHMENTS have been added in their entirety:

o The Geotechnical Report for Microgrid Design has been added as an attachment.

o The Geotechnical Report PV Array has been added as an attachement.

o The Technical Design Guide has been added as an attachment.

o The Final PH Soil Report has been added as an attachment.

(See ).

SOLICITATION, OFFER,

AND AWARD

(Construction, Alteration, or Repair)

IMPORTANT - The "offer" section on the reverse must be fully completed by offeror.

9. FOR

INFORMATION CALL:

NOTE: In sealed bid solicitations "offer" and "offeror" mean "bid and "bidder".

SOLICITATION

1. SOLICITATION NUMBER

5. REQUISITION/PURCHASE REQUEST NUMBER

CODE

6. PROJECT NUMBER

8. ADDRESS OFFER TO

4. CONTRACT NUMBER

7. ISSUED BY

10. THE GOVERNMENT REQUIRES PERFORMANCE OF THE WORK DESCRIBED IN THESE DOCUMENTS (Title, identifying number, date)

11. The contractor shall begin performance within

12a. THE CONTRACTOR MUST FURNISH ANY REQUIRED PERFORMANCE AND PAYMENT BONDS?

(If "YES", indicate within how many calendar days after award in Item 12b.)

13. ADDITIONAL SOLICITATION REQUIREMENTS:

a. Sealed offers in original and

b. An offer guarantee

c. All offers are subject to the (1) work requirements, and (2) other provisions and clauses incorporated in the solicitation in full text or by reference.

d. Offers providing less than

STANDARD FORM 1442 (REV. 12/2022)

Prescribed by GSA - FAR (48 CFR) 53.236-1(d) calendar days for Government acceptance after the date offers are due will not be considered and will be rejected.

is, is not required.

local time containing offers shall be marked to show the offeror's name and address, the solicitation number, and the date and time offers are due.

(date). If this is a sealed bid solicitation, offers will be publicly opened at that time. Sealed envelopes copies to perform the work required are due at the place specified in Item 8 by (hour) award, YES NO notice to proceed. This performance period is mandatory negotiable.

calendar days and complete it within calendar days after receiving

a. NAME b. TELEPHONE NUMBER (Include area code) (NO COLLECT CALLS)

12b. CALENDAR DAYS

2. TYPE OF SOLICITATION

SEALED BID (IFB)

INVITATION FOR BID

NEGOTIATED (RFP)

REQUEST FOR PROPOSAL

3. DATE ISSUED PAGE OF PAGES

759kWh

W9123826RA016 28 MAY 2026

NA

W075 ENDIST SAN FRAN

KO CONTRACTING DIVISION, 450 GOLDEN GATE AVENUE

SAN FRANCISCO, CA 94102-3406

UNITED STATES

NAIRI FREEMAN, EMAIL: NAIRI.FREEMAN@USACE.ARMY.MIL, TELEPHONE: (415)

503-6574

W91238

NAIRI FREEMAN (415) 503-6574

PROJECT TITLE: U.S. ARMY 63RD READINESS DIVISION MILCON ERCIP MICROGRID

LOCATION: MOUNTAIN VIEW, SANTA CLARA COUNTY, CALIFORNIA

The work includes installation of a microgrid system that provides energy resilience for 14+ days for mission critical functions, utilizing renewable and fossil fuel energy sources; will have full islanding capability and incorporation a ground-mounted photovoltaic (PV) solar system with low voltage switchgear for building energy shifting; a 750 kWh battery energy storage system (BESS); and an 800kWh diesel backup generation system, with a 10,000 gallon fuel storage tank. The microgrid system will include a master microgrid controller, and automatic smart switches controlling the generation resources within the Reserve Center. The microgrid will be installed on a closed restricted network (CRN) requiring an Authority to Operate (ATO) IAW DODI 8510.01. System cybersecurity requirements will be designed IAW UFC 4-010-06 "Cybersecurity for Facility Related Control Systems.”

THE NORTH AMERICAN INDUSTRY CLASSIFICATION SYSTEM (NAICS) CODE APPLICABLE TO THIS ACQUISITION IS 237130.

ESTIMATED COSTRANGE IS BETWEEN $10,000,000 AND $25,000,000.

FUNDS ARE NOT PRESENTLY AVAILABLE FOR THIS ACQUISITION. NO CONTRACT AWARD WILL BE MADE UNTIL APPROPRIATED FUNDS ARE MADE AVAILABLE. SEE

FAR CLAUSE 52.232-18 AVAILABILITY OF FUNDS

OFFEROR QUESTIONS

QUESTIONS RELATING TO THIS SOLICITATION AND TECHNICAL INQUIRIES WILL BE SUBMITTED VIA EMAIL TO THE ASSIGNED CONTRACT SPECIALIST.

INQUIRIES MUST BE RECEIVED NO LATER THAN 14 CALENDAR DAYS PRIOR TO THE PROPOSAL DUE DATE.

1 732

1 12:00PM

31 JULY 2026

INSTALL MICROGRID, 750kW PV, 750kWh BESS, & 800kW GENERATOR

SYSTEM - US ARMY RESERVES 63D READINESS DIVISION

SECTION TABLE OF CONTENTS

DIVISION 01 - GENERAL REQUIREMENTS

SECTION 01 11 00

SUMMARY OF WORK

02/24

PART 1 GENERAL

1.1 SUBMITTALS

1.2 WORK COVERED BY CONTRACT DOCUMENTS

1.2.1 Project Description

1.2.2 Location

1.3 OCCUPANCY OF PREMISES

1.4 EXISTING WORK

1.5 LOCATION OF UNDERGROUND UTILITIES

1.5.1 Notification Prior to Excavation

PART 2 PRODUCTS

PART 3 EXECUTION

-- End of Section Table of Contents --

SECTION 01 11 00 Page 1

SECTION 01 11 00

SUMMARY OF WORK

02/24

PART 1 GENERAL

1.1 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:

1.2 WORK COVERED BY CONTRACT DOCUMENTS

1.2.1 Project Description

The work includes a fully usable and complete smart microgrid system that is capable of managing itself, operating autonomously in island mode or grid connected, and seamlessly connecting to and disconnecting from the electric utility grid for the exchange of power. Under normal operations, the microgrid will generate power to serve the 63d Readiness Division HQ campus in parallel with commercial power from PG&E, the local electric utility. The microgrid will provide energy resilience to the campus for 14+ days independent from the local electrical grid. The microgrid system will therefore have full islanding capability. The microgrid system will incorporate distributed energy resources (DERs) including ground-mounted 750kWdc photovoltaic (PV) solar system, 750kWh battery energy storage system (BESS), and two 400kW diesel backup generators with a 10,000 gallon fuel storage tank. The PV system will be installed on the ground south of the headquarters building as shown on the drawings. The microgrid system will include a microgrid controller, and automatic smart switches controlling the generation resources within the campus. The microgrid will be installed on a closed restricted network (CRN). A Interconnection and New Service application have been approved by PG&E. The Contractor may need to resubmit documentation to PG&E for the Interconnection and New Service application dependent upon construction schedule and PG&E requirements. The complete and operational microgrid system will include the following:

a. Microgrid control system (MCS). Obtain Army Authority To Operate (ATO) for the system.

b. Four generator quick disconnects: Two at HQ Building, one at the Warehouse Building, and one at the Maintenance Shop.

c. 750kWdc photovoltaic system, located as shown on the plans.

d. Battery Energy Storage System (BESS), with two 500kW inverters and battery capacity of 750kWh located as shown on the plans.

e. New medium voltage distribution service from PG&E to feed a new service disconnect and a new switchgear lineup.

SECTION 01 11 00 Page 2

f. New medium voltage distribution service from PG&E to feed a new service disconnect and a new switchgear lineup.

g. Switchgear lineup will be in an enclosure which provides a conditioned space for the switchgear, microgrid controller and associated maintenance.

h. New building electrical service system from switchgear to two new transformers for each existing HQ building service in a radial configuration. Coordination with PG&E for the removal of the existing services and obtaining final permits with PG&E for the new service.

i. Two 400kW diesel backup generators with a 10,000 gallon fuel storage tank.

*3

j. The campus site has a minimum load of approximately 150kW, an average load of approximately 300kW, and a peak of around 600kW.

1.2.2 Location

The work is located at the 63d Readiness Division HQ Campus, approximately as indicated. The exact location will be shown by the Contracting Officer.

1.3 OCCUPANCY OF PREMISES

Building(s) will be occupied during performance of work under this Contract.

Before work is started, arrange with the Contracting Officer a sequence of procedure, means of access, space for storage of materials and equipment, and use of approaches, corridors, and stairways.

1.4 EXISTING WORK

In addition to FAR 52.236-9 Protection of Existing Vegetation, Structures, Equipment, Utilities, and Improvements:

a. Remove or alter existing work in such a manner as to prevent injury or damage to any portions of the existing work which remain.

b. Repair or replace portions of existing work which have been altered during construction operations to match existing or adjoining work, as approved by the Contracting Officer. At the completion of operations, existing work must be in a condition equal to or better than that which existed before new work started.

1.5 LOCATION OF UNDERGROUND UTILITIES

Obtain digging permits prior to start of excavation, and comply with Installation requirements for locating and marking underground utilities.

Contact local utility locating service a minimum of 48 hours prior to excavating, to mark utilities, and within sufficient time required if work occurs on a Monday or after a Holiday. Verify existing utility locations indicated on contract drawings, within area of work.

Identify and mark all other utilities not managed and located by the local utility companies. Scan the construction site with Ground Penetrating Radar (GPR), electromagnetic, or sonic equipment, and mark the surface of

SECTION 01 11 00 Page 3 the ground, pier deck or paved surface where existing underground utilities are discovered. Verify the elevations of existing piping, utilities,and any type of underground obstruction not indicated, or specified to be removed, that is indicated or discovered during scanning, in locations to be traversed by piping, ducts, and other work to be conducted or installed. Verify elevations before installing new work closer than nearest manhole or other structure at which an adjustment in grade can be made.

1.5.1 Notification Prior to Excavation

Notify the Contracting Officer at least 15 days prior to starting excavation work.

PART 2 PRODUCTS

Not used.

PART 3 EXECUTION

Not used.

-- End of Section --

SECTION 01 11 00 Page 4

SECTION TABLE OF CONTENTS

DIVISION 26 - ELECTRICAL

SECTION 26 37 13

MICROGRID CONTROL SYSTEM

02/24

PART 1 GENERAL

1.1 SUMMARY

1.1.1 System Requirements

1.1.1.1 General MCS Requirements

1.1.1.2 Symbols, Definitions, and Abbreviations

1.1.1.3 System Units and Accuracy

1.2 RELATED SECTIONS

1.2.1 Cybersecurity Requirements

1.2.2 Distributed Energy Resources

1.3 REFERENCES

1.4 ACRONYMS

1.5 DEFINITIONS

1.5.1 IEEE Stds Dictionary

1.5.2 ASTM E772

1.5.3 Anti-Islanding

1.5.4 Automatic Transfer Switch (ATS)

1.5.5 Base Load Power DER

1.5.6 Black Start

1.5.7 Distributed Energy Resource Management System (DERMS)

1.5.8 Firm Electrical Output DER

1.5.9 Grid Following

1.5.10 Grid Forming

1.5.11 Grid Forming DER

1.5.12 Human-Machine Interface (HMI)

1.5.13 Inverter-Based DER

1.5.14 Islanding

1.5.15 Load Following DER

1.5.16 Microgrid

1.5.17 Point of Common Coupling (PCC)

1.5.18 Power Quality Correcting DER

1.6 ADMINISTRATIVE REQUIREMENTS

1.6.1 Pre-Installation Meeting

1.6.1.1 Phasing Plan

1.7 SUBMITTALS

1.8 DATA PACKAGE AND SUBMITTALS REQUIREMENTS

1.9 PROJECT SEQUENCING

1.9.1 Sequencing for Submittals

1.9.2 Sequencing for Activities

1.10 STANDARD MATERIALS AND PRODUCTS

1.11 QUALITY ASSURANCE AND QUALITY CONTROL

1.11.1 Inspection Reports

1.11.2 Traceability and Markings

1.11.3 Proof of Performance

1.11.4 Documented ISO 9001 Compliance

1.11.5 Qualifications

SECTION 26 37 13 Page 1

1.11.6 Documentation

1.12 REGULATORY REQUIREMENTS

1.12.1 Utility Interconnect Contract

1.13 DELIVERY, STORAGE, AND HANDLING

1.13.1 General Requirements

1.13.2 Handling

1.13.3 Storage

1.14 SAFETY REQUIREMENTS

1.14.1 Grounding and Bonding

1.14.2 Anti-Islanding Protection

1.15 PROJECT AND SITE CONDITIONS

1.15.1 Environmental Conditions

1.15.2 Utility Interconnection Requirements

1.15.3 Utility Privatization Ownership Requirements

1.15.3.1 Ownership

1.15.3.2 Coordination

1.15.4 Existing Conditions

1.15.4.1 External Utility Distribution System

1.15.4.2 Point of Interconnection Equipment

1.16 OPERATION AND MAINTENANCE (O&M) INSTRUCTIONS

PART 2 PRODUCTS

2.1 SYSTEM DESCRIPTION AND OPERATIONAL REQUIREMENTS

2.1.1 Microgrid System Architecture

2.1.2 Microgrid Equipment

2.1.2.1 Utility Service; Point of Common Coupling (Point of

Interconnection)

2.1.2.2 Power Generating Assets

2.1.2.3 Controlled Switches, Breakers, and Devices

2.1.3 Functional Requirements and Design Parameters

2.1.3.1 Autonomy

2.1.3.2 Supported Load Profile

2.1.3.3 Off-grid (Island) System Endurance

2.1.3.4 Energy Surety and Redundancy

2.1.3.5 Load Shedding Requirements

2.1.3.6 Restoration and Resynchronization

2.1.3.7 Power System Studies

2.1.3.8 Expandability

2.1.3.9 Real-time Data Export

2.1.3.10 Bi-Directional 'Blinkless' Transitions

2.1.3.11 Island-mode Black Start Capability

2.1.3.12 Control System Resilience and Redundancy

2.1.3.13 Operational Mode Prioritization

2.1.3.14 Communication with Protection System

2.1.4 Microgrid Control System Multi-Level Architecture

2.1.4.1 MCS Primary Control (High-Speed Communications)

2.1.4.1.1 Power Flow Management

2.1.4.1.2 Fault Detection & Isolation

2.1.4.1.3 Operational Safety

2.1.4.1.4 State Transition Management

2.1.4.1.5 Emergency Response

2.1.4.2 Low-Speed Communications and Control - Secondary Control

2.1.4.2.1 Load Shedding

2.1.4.2.2 Economic Dispatch

2.1.4.2.3 Reactive Control

2.1.4.2.4 Load Shaping

2.1.4.2.5 Voltage Control

2.1.4.3 Low-Speed Communications and Control - Tertiary Control

SECTION 26 37 13 Page 2

(optimization)

2.1.4.3.1 Energy Optimization

2.1.4.3.2 Grid Interaction

2.1.4.3.3 Demand Response

2.1.4.3.4 Fuel Management

2.1.4.3.5 Curtailment Requests

2.1.4.3.6 HMI & Visualization

2.1.4.3.7 Real-time Analytics

2.1.4.3.8 Renewable Energy Forecasting

2.1.4.4 MCS Physical Interface Level

2.1.4.4.1 DER Firewall

2.1.4.4.2 Data Concentrators

2.1.4.4.3 Protocol Converter

2.1.4.5 MCS Connection to External Communications Systems

2.1.4.5.1 UMCS

2.1.4.6 Protection & Metering Interfaced with MCS

2.1.4.6.1 Remote I/O

2.1.4.6.2 Meters, PQM

2.1.4.6.3 Protective Relays

2.1.4.7 Microgrid Assets Controlled by MCS

2.1.4.7.1 External Grid PCC

2.1.4.7.2 Grid-Forming DER(s)

2.1.4.7.3 Grid-Following DER(s)

2.1.4.7.4 ESS

2.1.4.7.5 Dispatchable Load(s)

2.1.4.7.6 Controllable Load(s)

2.1.4.8 State I: Normal Operation (Grid-Tie Mode, Standby)

2.1.4.8.1 MCS Primary Control (high-speed)

2.1.4.8.2 MCS Secondary Control (low-speed)

2.1.4.8.3 MCS Tertiary Control (long-term optimization)

2.1.4.8.4 MCS Physical Interface Level

2.1.4.8.5 MCS Connection to External Communications Systems

2.1.4.8.6 Protection & Metering Interfaced with MCS

2.1.4.8.7 Microgrid Assets Controlled by MCS

2.1.4.9 State 2: Isolation from External Utility (Islanding;

Transient State)

2.1.4.9.1 MCS Primary Control (high-speed)

2.1.4.9.2 MCS Secondary Control (low-speed)

2.1.4.9.3 MCS Tertiary Control (long-term optimization)

2.1.4.9.4 MCS Physical Interface Level

2.1.4.9.5 MCS Connection to External Communications Systems

2.1.4.9.6 Protection & Metering Interfaced with MCS

2.1.4.9.7 Microgrid Assets Controlled by MCS

2.1.4.10 State 3: Microgrid Formation (Soft Transition or Black

Start)

2.1.4.10.1 MCS Primary Control (high-speed)

2.1.4.10.2 MCS Secondary Control (low-speed)

2.1.4.10.3 MCS Tertiary Control (long-term optimization)

2.1.4.10.4 MCS Physical Interface Level

2.1.4.10.5 MCS Connection to External Communications Systems

2.1.4.10.6 Protection & Metering Interfaced with MCS

2.1.4.10.7 Microgrid Assets Controlled by MCS

2.1.4.11 State 4: Islanded Operation (Optimized Operation for

Resilience and Endurance)

2.1.4.11.1 MCS Primary Control (high-speed)

2.1.4.11.2 MCS Secondary Control (low-speed)

2.1.4.11.3 MCS Tertiary Control (long-term optimization)

2.1.4.11.4 MCS Physical Interface Level

2.1.4.11.5 MCS Connection to External Communications Systems

SECTION 26 37 13 Page 3

2.1.4.11.6 Protection & Metering Interfaced with MCS

2.1.4.11.7 Microgrid Assets Controlled by MCS

2.1.4.12 State 5: Re-Synchronization Back to External Utility

(Soft Transition Only; Transient State)

2.1.4.12.1 MCS Primary Control (high-speed)

2.1.4.12.2 MCS Secondary Control (low-speed)

2.1.4.12.3 MCS Tertiary Control (long-term optimization)

2.1.4.12.4 MCS Physical Interface Level

2.1.4.12.5 MCS Connection to External Communications Systems

2.1.4.12.6 Protection & Metering Interfaced with MCS

2.1.4.12.7 Microgrid Assets Controlled by MCS

2.1.4.13 State 6: Testing and Diagnostic State

2.1.5 Microgrid Control System Sequences of Control

2.1.5.1 SOC-001: State Transition

2.1.5.2 SOC-002: Fault Isolation

2.1.5.3 SOC-003: Emergency Shutdown

2.1.5.4 SOC-004: Demand Response

2.1.5.5 SOC-005: (External) Emergency Response

2.1.5.6 SOC-006: Blackout Response

2.1.5.7 SOC-007: Communications Failure Response

2.1.5.8 SOC-100: Normal Grid-tie Mode Stable Operation

2.1.5.9 SOC-101: Soft transition to Island Mode

2.1.5.10 SOC-102: Grid Support Services

2.1.5.11 SOC-103: Grid-tied Load Shedding

2.1.5.12 SOC-104: Peak Shaving

2.1.5.13 SOC-105: Voltage Regulation

2.1.5.14 SOC-106: Energy Optimization

2.1.5.15 SOC-108: Demand Response

2.1.5.16 SOC-109: Renewable Curtailment

2.1.5.17 SOC-110: HVAC Optimization

2.1.5.18 SOC-111: Directed Grid Disconnect

2.1.5.19 SOC-201: Black Start

2.1.5.20 SOC-202: Island Load Shedding

2.1.5.21 SOC-203: Generation Synchronization

2.1.5.22 SOC-301: Soft Transition Completion

2.1.5.23 SOC-302: Black Start Completion

2.1.5.24 SOC-400: Island Mode Stable Operation

2.1.5.25 SOC-401: Load Balancing

2.1.5.26 SOC-402: Island Fault Isolation

2.1.5.27 SOC-403: Reconnection Pre-check

2.1.5.28 SOC-404: Island Load Shedding

2.1.5.29 SOC-405: Island Voltage Regulation

2.1.5.30 SOC-406: Island Energy Optimization

2.1.5.31 SOC-407: Island Demand Response, Dispatchable Generation

& Consumption

2.1.5.32 SOC-408: Island Fuel Management

2.1.5.33 SOC-409: Island Renewable Curtailment

2.1.5.34 SOC-501: Reconnection Pre-check

2.1.5.35 SOC-502: Reconnection Safety Check

2.1.5.36 SOC-503: Safety Confirmation

2.1.5.37 SOC-504: Reconnection Sequence

2.1.6 Control Power

2.1.7 Protection and Control Integration

2.1.8 Energy Management Functions

2.1.8.1 Dispatch Requirements

2.1.8.2 Blackstarting Requirements

2.1.8.3 Restoration Requirements

2.1.8.4 DER Mode Selection

2.1.8.5 Load Shedding

SECTION 26 37 13 Page 4

2.1.9 Energy Reporting and Monitoring

2.1.9.1 UMCS Integration

2.1.10 Fault Management and Isolation

2.1.11 Data Security and Encryption

2.1.12 Time Synchronization

2.1.13 Communication Standards

2.1.14 Failover and Redundancy

2.1.15 Data Storage

2.1.16 Utility Interconnect

2.1.16.1 Utility Interconnection Agreement

2.1.16.2 Protection System Interface & Coordination

2.2 MICROGRID CONTROL SYSTEM COMPONENT DEVICE REQUIREMENTS

2.2.1 Product Certifications

2.2.2 Product Sourcing

2.2.3 General Requirements

2.2.4 Nameplates and Identification

2.2.5 Warning Labels

2.2.6 Product Data Sheets

2.2.7 Firmware and Software Updates

2.2.8 Environmental Ratings

2.3 CONTROL HARDWARE

2.3.1 General Requirements

2.3.2 MCS Modules

2.3.3 Power Supply Module

2.3.4 MCS Program Storage/Memory Requirements

2.3.5 MCS Input/Output Characteristics

2.3.6 MCS Wiring Connections

2.3.7 MCS Diagnostics

2.3.8 Interface with DER

2.3.9 Protocols

2.3.9.1 Modbus (Modicon Communication Protocol)

2.3.9.2 MIL-STD-3071

2.3.9.3 IEC 61850

2.3.9.4 DNP 3.0

2.3.9.5 ANSI C37.118

2.3.9.6 Coordination

2.3.10 Data Concentrators

2.3.11 Gateways

2.3.12 Ethernet Switches

2.3.12.1 Product Description

2.3.12.2 Environmental Requirements

2.3.12.3 Power Supply

2.3.12.4 Encryption

2.3.12.5 Passwords

2.3.12.6 Port Security

2.3.12.7 Traffic Shaping

2.3.12.8 Ports

2.3.13 Network Design

2.3.13.1 Firewalls

2.3.13.2 Remote Engineering Access

2.3.13.3 Remote Control and Monitoring Access

2.3.13.4 Remote Internet Access

2.3.13.5 On-site LAN

2.3.13.6 Dedicated ADSL

2.3.14 Supervisory Dispatch Controllers

2.3.15 Human Machine Interface (HMI)

2.3.15.1 HMI Layout and Organization

2.3.15.2 Alarm and Event Management

2.3.16 Workstation Hardware (Desktop and Laptop)

SECTION 26 37 13 Page 5

2.3.16.1 Processor

2.3.16.1.1 Desktop

2.3.16.1.2 Laptop

2.3.16.2 Random Access Memory (RAM)

2.3.16.3 Communications Ports

2.3.16.3.1 Desktop

2.3.16.3.2 Laptop

2.3.16.4 Hard Drive and Controller

2.3.16.4.1 Desktop

2.3.16.4.2 Laptop

2.3.16.5 Optical Drive

2.3.16.6 Video Output

2.3.16.6.1 Desktop

2.3.16.6.2 Laptop

2.3.16.7 Network Interface

2.3.16.7.1 Desktop

2.3.16.7.2 Laptop

2.3.16.8 Monitor

2.3.16.8.1 Desktop

2.3.16.8.2 Laptop

2.3.16.9 Keyboard and Smart Card Reader

2.3.16.9.1 Desktop

2.3.16.9.2 Laptop

2.3.16.10 Mouse

2.3.16.10.1 Desktop

2.3.16.10.2 Laptop

2.3.16.11 Printers

2.3.16.12 Operating System (OS)

2.3.16.13 Virus Protection Software

2.3.16.14 Disk Imaging (Backup) Software

2.3.16.15 Supported Field Control Protocols

2.3.17 Remote Access Hardware

2.3.17.1 Hardware Requirements

2.3.17.1.1 Firewalls

2.3.17.1.2 VPN Gateway

2.3.17.1.3 Multi-Factor Authentication

2.3.17.2 Redundancy and Failover

2.3.17.3 Remote Access Protocols

2.3.17.4 Data Encryption

2.3.17.5 Hardware Maintenance

2.3.17.6 Logging and Monitoring

2.3.17.7 Compliance and Certification

2.3.18 Data Logging and Event Recording

2.3.18.1 Types of Data to be Logged

2.3.18.2 Data Logging Frequency

2.3.18.3 Data Storage Duration

2.3.18.4 Data Backup and Redundancy

2.3.18.5 Event Recording

2.3.18.6 Access to Logged Data

2.3.18.7 Data Security

2.4 COMPUTER HARDWARE

2.5 COMPUTER SOFTWARE

2.5.1 Web Services - API access

2.6 RACKS AND ENCLOSURES

2.6.1 Enclosures

2.6.1.1 Outdoors

2.6.1.2 Mechanical and Electrical Rooms

2.6.1.3 Other Locations

2.6.2 Equipment Racks

SECTION 26 37 13 Page 6

PART 3 EXECUTION

3.1 PLANNING

3.2 DEVELOPMENT

3.3 FACTORY TESTING

3.3.1 FACTORY TESTING COMPLIANCE

3.3.2 FACTORY TEST SETUP

3.3.3 Factory Test Procedures

3.3.4 Factory Test Report

3.4 Real Time Hardware in the Loop (HIL) Testing

3.5 EXISTING CONDITIONS

3.6 ASSESSMENT CONSIDERATIONS

3.6.1 Documentation and Reporting

3.7 FUTURE EXPANSION CAPABILITIES

3.8 DRAWINGS AND CALCULATIONS

3.8.1 Network Bandwidth and Usage Calculations

3.8.2 Draft As-Built Drawings

3.9 INSTALLATION REQUIREMENTS

3.9.1 General

3.9.2 Isolation, Penetrations, Clearance

3.10 INSTALLATION OF EQUIPMENT

3.10.1 Vibration and Seismic Control

3.10.2 Wire and Cable

3.10.2.1 LAN Cables and Connecting Hardware

3.10.2.2 Unshielded Twisted Pair Patch Panels

3.10.2.3 Fiber Optic Patch Panels

3.10.2.4 Equipment Racks

3.10.2.5 Rack Mounted Equipment

3.10.2.6 Termination

3.10.2.7 Unshielded Twisted Pair Cable

3.10.2.8 Shielded Twisted Pair Cables

3.10.2.9 Fiber Optic Cable

3.10.3 Pathways

3.10.4 Identification

3.10.5 Grounding and Bonding

3.10.6 Reference Voltages

3.10.7 Grounding

3.10.8 Surge Protection

3.11 APPLICATION

3.12 INTEGRATION OF FIELD CONTROL SYSTEMS

3.12.1 Install Control Hardware

3.12.2 Add Field Control System

3.12.3 Configure Software

3.13 FIELD QUALITY CONTROL

3.13.1 Tests

3.13.1.1 Dispatch Functions

3.13.1.2 Transition Functions

3.13.1.3 Grid-Following Synchronization

3.13.1.4 Islanded Grid-Forming Synchronization

3.13.1.5 Load-Following, Load-Shedding, and Energy Management

3.13.2 Examination and Inspection

3.13.3 Manufacturer Field Startup and Service

3.14 STARTUP TESTING

3.14.1 Testing Wire and Cable

3.14.1.1 Unshielded Twisted Pair Testing

3.14.1.2 Category 5E Circuits Testing

3.14.1.3 Shielded Twisted Pair Wiring Testing

3.14.1.4 Fiber Optic Cable Testing

SECTION 26 37 13 Page 7

3.14.1.5 Inspection

3.14.1.6 Final Verification Tests

3.14.2 Protective Relays Communications Testing

3.14.2.1 Points List Testing

3.15 PERFORMANCE VERIFICATION TESTING (PVT)

3.15.1 Phase I Testing (Standalone Test)

3.15.2 Phase II Testing (Integration Test)

3.15.3 Phase III Testing (Endurance Test)

3.16 TRAINING

3.16.1 General

3.16.2 Operators Training

3.16.3 Maintenance Training

3.17 MAINTENANCE AND SERVICE

3.17.1 Work Coordination

3.17.2 Work Control

3.17.3 Working Hours

3.17.4 Equipment Repairs

3.17.5 Replacement, Modernization, Renovation

3.17.6 Access to MCS Equipment

3.17.7 Records, Logs, Progress Reports

3.17.8 Periodic Maintenance and Inspection

3.17.9 Preventive Maintenance Requirements

3.17.9.1 Preventive Maintenance Work Plan

3.17.10 Service Call Reception

3.17.11 Service Call Work Warranty

3.17.12 Warranties and Guarantees

3.18 EMERGENCY RESPONSE PLAN

3.19 TROUBLESHOOTING AND DIAGNOSTICS

3.20 AS-BUILT DOCUMENTS

3.21 ON-GOING MAINTENANCE MATERIALS

3.22 PORTALS, CLOSED, OR TRANSFERRED TO GOVERNMENT

-- End of Section Table of Contents --

SECTION 26 37 13 Page 8

SECTION 26 37 13

MICROGRID CONTROL SYSTEM

02/24

PART 1 GENERAL

1.1 SUMMARY

The Microgrid Control System defined herein monitors and controls the operation of the microgrid equipment. This specification refers only to that control system and does not include specification of the connected equipment which comprises the microgrid such as Distributed Energy Resources (DERs), controlled loads, distribution or utilization circuits, low, medium, or high-voltage protective devices, or other similar components specified elsewhere.

1.1.1 System Requirements

Provide an electrical Microgrid Control System (MCS) as specified and indicated, and in accordance with the following characteristics:

1.1.1.1 General MCS Requirements

a. Scope of Control: The MCS controls the microgrid system. The microgrid is defined as a bounded electrical system with a single point of interconnection with an external grid. The system includes DERs, distribution devices, dispatchable and non-dispatchable loads, controls, and communication systems.

b. Fault Management: MCS supervisory monitoring and control functions include but are not limited to automated fault detection, microgrid isolation from the external electrical grid, and internal system reconfiguration capabilities to maintain critical load supply.

c. Component Standards: Provide components and technology which are commercial, warrantied, and intended for permanent installation.

Materials and equipment must be standard unmodified products of a manufacturer regularly engaged in the manufacturing of such products.

Units of the same type of equipment must be products of a single manufacturer. Items of the same type and purpose must be identical and supplied by the same manufacturer, unless replaced by a new version approved by the Government.

d. Island Mode Operation: Ensure the Microgrid Control system operates the microgrid in island mode, paralleling either one or more than one disparate source of generation, with at least one grid-forming DER with droop control.

e. Black Start Capability: Equip the MCS to manage the microgrid black start procedure. Initiate the startup of more than one firm-generation grid-forming DER asset(s) after an unplanned external grid outage.

f. Load Management: Incorporate functionality within the MCS to dispatch DER and direct load shedding, ensuring the islanded system generation

SECTION 26 37 13 Page 9 meets the critical load within the system boundary.

g. Operational Modes: Equip the MCS with functionality to direct transitions between operational modes, including but not limited to black start in island mode, automatic transition from grid-connected to islanded mode, resynchronization and reconnection to grid-connected mode from islanded mode, and system balancing. Manage energy to optimize both real and reactive power generation and consumption for microgrid-connected load resilience through DER and load dispatch.

h. Critical Load Uptime: For critical loads supplied by the microgrid, equip the MCS with functionality to support a minimum uptime of 99.9% as defined and required by UFC 3-520-02.

i. System Interface: Ensure the MCS is arranged and interconnected such that it serves as the single point of interface with all microgrid DERs, DER Management System (DERMS), or UMCS. If necessary, allow the microgrid control system to perform UMCS functions required to dispatch microgrid resources.

j. Monitoring and Control: Equip the MCS with supervisory monitoring and control functions, including but not limited to: Point of Common Coupling (PCC) monitoring and control, frequency control, load shedding, anti-islanding, low- or high- voltage or frequency ride-through, voltage (reactive power) control, remote breaker control and monitoring in accordance with facility SOP, synchronization, and power quality monitoring.

k. Grid Interface: Coordinate the microgrid and microgrid system controller to present to the larger grid as a single entity with a single point of electrical interconnection and a single control and communication interface between the microgrid and external grid.

Ensure all MCS control and reporting functions appear as a single entity to all external devices. Execute functions defined herein from that single point of interconnection.

l. Human Machine Interface: System includes human-machine interface with graphical interface into the MCS. Incorporate a primary interface position where all described microgrid control and HMI functions are accessible. The HMI must allow for graphical navigation between systems, graphical representations of systems and interconnection, access to real-time data for systems, ability to override points in a system, and access to all supervisory monitoring and control functions.

m. Software Licenses: Provide all necessary software documentation, configuration information, configuration tools, programs, drivers, and other software. Ensure they are licensed to and remain with the Government so that the Government or their agents can repair, replace, upgrade, and expand the system without subsequent or future dependence on the Contractor. Software licenses must not require periodic fees and be valid in perpetuity.

n. Documentation: Supply sufficient documentation and data, including rights to documentation and data, enabling the Government or their agents to execute work to repair, replace, upgrade, expand, and cyber-secure the system without subsequent or future dependence on the Contractor.

SECTION 26 37 13 Page 10

1.1.1.2 Symbols, Definitions, and Abbreviations

Use symbols, definitions, and engineering unit abbreviations indicated in the contract drawings for displays, submittals and reports. For symbols, definitions and abbreviations not in the contract drawings use terms conforming at a minimum to IEEE Standards Dictionary as applicable.

1.1.1.3 System Units and Accuracy

Use metric (SI) for all electric and power units, all other units use English (inch-pound) units for displays, print-outs and calculations.

Ensure calculations have an accuracy of at least three significant figures and present values on displays and printouts to at least three significant figures.

1.2 RELATED SECTIONS

UFGS 25 05 11 CYBERSECURITY FOR FACILITY-RELATED CONTROL SYSTEMS

1.2.1 Cybersecurity Requirements

*1

Cybersecurity requirements related to this Section are specified in

25 05 11 CYBERSECURITY FOR FACILITY-RELATED CONTROL SYSTEMS.

1.2.2 Distributed Energy Resources

a. Evaluate reciprocating gensets in the microgrid for their operational mode as parallel to the utility grid, and prime/continuous. Where carbon-emitting gensets operate in parallel to the utility, ensure compliance with EPA Tier 4 emission guidelines. Determine if the utility contract permits parallel operation. Refer to Section 26 05 73

POWER SYSTEM STUDIES.

b. Ensure the microgrid control system interfaces with, providing control and communication as outlined throughout this specification for solar photovoltaic arrays provided under this contract using compatible micro-inverter technology. If necessary, ensure inverters can control real and reactive power and comply with grid interconnection standards, including IEEE 1547 . Refer to 26 31 00 FACILITY-SCALE

SOLAR PHOTOVOLTAIC (PV) SYSTEMS.

c. Integrate Energy storage systems (ESS) into the microgrid control system for purposes such as backup power. Ensure the ESS can control both charge and discharge, with real and reactive power capabilities.

Specify the storage capacity based on the microgrid's operational objectives and ROI considerations. Refer to Section 26 33 57 BATTERY

ENERGY STORAGE SYSTEM (BESS).

1.3 REFERENCES

INSTITUTE OF ELECTRICAL AND ELECTRONICS ENGINEERS (IEEE)

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

IEEE 1613 (2023) Environmental and Testing Requirements for Devices with

SECTION 26 37 13 Page 11

Communications Functions used with Electric Power Apparatus

IEEE 2030.7 (2017) The Specification of Microgrid Controllers

IEEE 2030.8 (2008) The Testing 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 C37.90.2 (2004; R 2010) Withstand Capability of Relay Systems to Radiated Electromagnetic Interference from Transceivers

IEEE C62.41.1 (2002; R 2008) Guide on the Surges Environment in Low-Voltage (1000 V and Less) AC Power Circuits

IEEE C62.41.2 (2002) Recommended Practice on Characterization of Surges in Low-Voltage (1000 V and Less) AC Power Circuits

IEEE Stds Dictionary (2009) IEEE Standards Dictionary: Glossary of Terms & Definitions

INTERNATIONAL ELECTROTECHNICAL COMMISSION (IEC)

IEC 60068-2-1 (2007) Environmental testing - Part 2-1:

Tests - Test A: Cold

IEC 60068-2-2 (2007) Environmental testing - Part 2-2:

Tests - Test B: Dry heat

IEC 60068-2-30 (2005; ED 3.0) Environmental Testing - Part 2-30: Tests - Test Db: Damp Heat, Cyclic (12 H + 12 H Cycle)

IEC 60068-2-78 (2012) Environmental testing - Part 2-78:

Tests - Test Cab: Damp heat, steady state

IEC 60255-1 (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

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

SECTION 26 37 13 Page 12

Tests On Measuring Relays And Protection Equipment - Section 3: Seismic Tests

IEC 60255-26 (2023) Measuring relays and protection equipment – Part 26: Electromagnetic compatibility requirements

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

- Part 4-4: Testing and measurement techniques - Electrical fast transient/burst immunity test

IEC 61000-4-8 (2009) Electromagnetic compatibility (EMC)

– Part 4-8: Testing and measurement techniques – Power frequency magnetic field immunity test

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

Programming Languages

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

INTERNATIONAL SOCIETY OF AUTOMATION (ISA)

ISA 5.2 (1976; R1992) Binary Logic Diagrams for Process Operations

ISA 18.2 (2016) Management of Alarm Systems for the Process Industries

ISA 101.01 (2015) Human Machine Interfaces for Process Automation Systems

NATIONAL ELECTRICAL MANUFACTURERS ASSOCIATION (NEMA)

NEMA 250 (2020) Enclosures for Electrical Equipment (1000 Volts Maximum)

NATIONAL FIRE PROTECTION ASSOCIATION (NFPA)

NFPA 70 (2023) National Electrical Code

NFPA 262 (2023) Standard Method of Test for Flame Travel and Smoke of Wires and Cables for Use in Air-Handling Spaces

U.S. DEPARTMENT OF DEFENSE (DOD)

MIL-STD-3071 (2023) Tactical Microgrid Communications and Control

U.S. FEDERAL COMMUNICATIONS COMMISSION (FCC)

FCC EMC (2002) FCC Electromagnetic Compliance Requirements

FCC Part 15 Radio Frequency Devices (47 CFR 15)

SECTION 26 37 13 Page 13

UNDERWRITERS LABORATORIES (UL)

UL 60950 (2000; Reprint Oct 2007) Safety of Information Technology Equipment

1.4 ACRONYMS

Acronym Term

ARC Communication Architecture

ATS Automatic Transfer Switch

DER Distributed Energy Resource

DERMS DER Management System

DFD Data Flow Diagram

DMS Distribution Management System

FAT Factory Acceptance Test

HIL Hardware in the Loop

HMI Human Machine Interface

IBR Inverter-Based Resource

IEC International Electrotechnical Commission

IEEE Institute of Electrical and Electronics Engineers

ISE Interconnection System Equipment

IT Information Technology

LAN Local Area Network

MCS Microgrid Control System

MEMS Micro-Electro-Mechanical Systems

NEC National Electric Code (NFPA 70)

NEMA National Electric Manufacturers Association

NFPA National Fire Protection Association

OT Operational Technology

PCC Point of Common Coupling

POI Point of Interface

SECTION 26 37 13 Page 14

Acronym Term

PV Photovoltaic

RPM Revolutions Per Minute

ROI Return on Investment

SAT Site Acceptance Test

SCADA Supervisory Control and Data Acquisition

SER Sequential Events Recorder

SOE Sequence of Events

SOP Standard Operating Procedure

UL Underwriters Laboratory

UPS Uninterruptible Power Suppl

1.5 DEFINITIONS

1.5.1 IEEE Stds Dictionary

For terms not explicitly defined in this section, refer to the IEEE Stds Dictionary .

1.5.2 ASTM E772

For terms related to solar energy, refer to ASTM E772 for definitions and standard terminology.

1.5.3 Anti-Islanding

A safety mechanism that detects when a microgrid has been separated from the main grid and ensures that the microgrid does not continue to feed power back into the disconnected grid.

1.5.4 Automatic Transfer Switch (ATS)

A switch that automatically transfers a power supply from its primary source to a backup source when it senses a failure or outage in the primary source.

1.5.5 Base Load Power DER

A DER that provides a constant output to meet minimum load requirements.

SECTION 26 37 13 Page 15

1.5.6 Black Start

The process of restoring a disabled or shut down microgrid to operation without relying on the external electric power transmission network.

1.5.7 Distributed Energy Resource Management System (DERMS)

A control system that allows for the centralized control of DERs within the microgrid, often integrated into the microgrid control system.

1.5.8 Firm Electrical Output DER

A DER capable of providing a guaranteed level of output under specified conditions.

1.5.9 Grid Following

A mode of operation where the DER adjusts its output based on grid conditions but cannot independently maintain grid voltage and frequency.

1.5.10 Grid Forming

A mode of operation where the DER can independently control voltage and frequency within a microgrid, effectively forming a grid.

1.5.11 Grid Forming DER

A DER capable of operating in a grid-forming mode, independently controlling voltage and frequency within a microgrid.

1.5.12 Human-Machine Interface (HMI)

The user interface that connects an operator to the controller in an industrial system, often a part of the microgrid control system.

1.5.13 Inverter-Based DER

A DER that uses an inverter to convert its output to alternating current (AC) for grid interconnection.

1.5.14 Islanding

Condition in which a microgrid operates independently and electrically isolated from the external grid.

1.5.15 Load Following DER

A DER that adjusts its output in real-time to match fluctuations in load demand.

1.5.16 Microgrid

A localized energy system consisting of DERs and loads capable of operating in parallel with, or independently from, the main power grid.

1.5.17 Point of Common Coupling (PCC)

The demarcation point between the owned electrical system of the microgrid and the utility distribution system.

SECTION 26 37 13 Page 16

1.5.18 Power Quality Correcting DER

A DER that provides ancillary services to improve power quality, such as voltage and frequency regulation.

1.6 ADMINISTRATIVE REQUIREMENTS

The contractor is responsible for the complete installation, testing, and commissioning of the Microgrid Control System (MCS) in accordance with the project's Division 01 Specification. The contractor must also coordinate with other trades and disciplines to ensure seamless integration of the MCS with other systems, including but not limited to DERs, UMCS, and existing utility infrastructure.

1.6.1 Pre-Installation Meeting

In accordance with UFC 1-300-02, a pre-installation meeting is required be held to discuss plans, procedures, responsibilities, and the impact on existing facilities. The meeting must include, but is not limited to, the following:

1.6.1.1 Phasing Plan

Prepare and submit a Phasing Plan that includes listing for duration and estimated start date for any and all outages of existing assets impacted by the installation of the MCS. Include outages or simulated outages related to testing as specified in Part 3. The phasing plan must be prepared in collaboration with PG&E.

Include in the submitted equipment phasing plan an Integration Plan for MCS with existing or planned assets, a detailed Phasing Plan outlining outages and coordination, and Risk Mitigation Strategies.

1.7 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-01 Preconstruction Submittals

Utility Interconnection Agreement ; G

Phasing Plan ; G

SD-02 Shop Drawings

Contractor Design Drawings ; G

Draft As-Built Drawings ; G

Microgrid Control System HMI Graphical Mockup ; G

SD-03 Product Data

Product Data Sheets ; G

SECTION 26 37 13 Page 17

Computer Hardware Specifications ; G

Computer Software Specifications ; G

SD-04 Samples

Enclosure Keys ; G

SD-05 Design Data

Power System Studies ; G

Microgrid System Architecture Diagram; G

SD-06 Test Reports

Comprehensive Execution Plan ; G

Site Assessment Survey ; G

Factory Test Procedures ; G

Factory Test Report ; G

PVT Testing Procedures ; G

PVT Phase I Testing Report ; G

PVT Phase II Testing Report ; G

PVT Phase III Testing Report ; G

Startup Testing Plan ; G

Startup Testing Report ; G

Factory Acceptance Test Reports ; G

Pre-construction QC checklist ; G

Post-construction QC checklist ; G

SD-07 Certificates

Regulatory Compliance Documentation ; G

ISO 9001 Compliance Certificate ; G

Installer Qualifications ; G

Utility Interconnect Contract

SD-10 Operation and Maintenance Data

Emergency Response Plan ; G

Training Documentation ; G

SECTION 26 37 13 Page 18

Operation And Maintenance Instructions; G

SD-11 Closeout Submittals

Enclosure Keys ; G

Closeout QC Checklist ; G

Microgrid System Model ; G

1.8 DATA PACKAGE AND SUBMITTALS REQUIREMENTS

Technical data packages consisting of computer software and technical data (meaning technical data which relates to computer software) which are specifically identified in this project and which may be defined/required in other specifications must be delivered strictly in accordance with the CONTRACT CLAUSES and in accordance with the Contract Data Requirements List, DD Form 1423. Data delivered must be identified by reference to the particular specification paragraph against which it is furnished. All submittals not specified as technical data packages are considered shop drawings under the Federal Acquisition Regulation Supplement (FARS) and must contain no proprietary information and must be delivered with unrestricted rights.

1.9 PROJECT SEQUENCING

Table I outlines the sequencing of submittals as detailed in the SUBMITTALS paragraph (indicated by an 'S' in the 'TYPE' column) and activities as described in PART 3 EXECUTION (marked by an 'E' in the 'TYPE' column).

1.9.1 Sequencing for Submittals

The sequencing for submittals indicates the final date by which the submittal must be provided. After submission, the Government will review as outlined in 01 33 00 SUBMITTAL PROCEDURES. If the Government doesn't accept the submittal, revise the submittal and resubmit within 14 days of receiving the rejection notification. Each re-submission will undergo an additional Government review, and this process will continue until the Government accepts the submittal.

1.9.2 Sequencing for Activities

The sequencing specified for activities indicates the earliest activity may begin.

TABLE I - PROJECT SEQUENCING

ITEM TYPE DESCRIPTION SEQUENCING (START OF ACTIVITY

or DEADLINE FOR SUBMITTAL)

Commercial contracts and Pos in place

Resource plan

Project schedule

Monthly progress reports

SECTION 26 37 13 Page 19

ITEM TYPE DESCRIPTION SEQUENCING (START OF ACTIVITY

or DEADLINE FOR SUBMITTAL)

Kick-off meetings

Internal/External audit review meetings

Detailed functional design specification

Schematic Single Line Diagram

Equipment layout drawings

Studies completed and validated

Factory Acceptance Plan

1 Acceptance of Factory Test Report

2 S Existing Conditions Report (site assessment survey)

3 S Contractor Design Drawings

4 S Product Data Sheets and Certificate of Networthiness Documentation

5 S MCS IP Network Bandwidth Usage Estimate

6 S Pre-construction QC Checklist

Isolation, commissioning, testing, and restoration plans for system

Site readiness checklist

7 E Install MCS

8 E Start-Up Procedures and Start-Up Testing

9 S Post-Construction QC Checklist

10 S Computer Software

11 S Start-Up and Start-Up Testing Report

12 S Draft As-Built Drawings

13 S PVT Phase I Procedures

14 E PVT Phase I AAO #13 and #12

15 S PVT Phase I Report

16 S Preventive Maintenance Work Plan

17 S O&M Instructions

SECTION 26 37 13 Page 20

ITEM TYPE DESCRIPTION SEQUENCING (START OF ACTIVITY

or DEADLINE FOR SUBMITTAL)

18 S Basic Training Documentation

19 E Basic Training (PVT Phase II)

20 S PVT Phase II Report

21 S Final As-Built Drawings

22 S Advanced Training Documentation

23 E Advanced Training ACO #19

24 S Refresher Training Documentation

25 E Refresher Training between

26 S Closeout QC Checklist

Con…