Section 01

Executive Summary

EnergizeOS™ is a commercial-grade, hardware-software integrated EMS for industrial and commercial BESS, microgrid, and grid-interconnection applications.

Developed by Energize Solutions Inc., EnergizeOS™ integrates a ruggedized ECP control panel, a real-time embedded strategy execution engine, and an OTA management platform into a productized, auditable control framework with defined engineering boundaries at every layer.

⚡

Core principle: Protection responsibility (relay) is permanently separated from control responsibility (EMS). This boundary is immutable — enforced in hardware and software at every deployment.

Core Value Summary

Dimension	Capability	Validated Outcome
Cost Optimization	TOU dispatch + demand charge management + DG fuel coordination	10–35% electricity or fuel cost reduction
Grid Transition	C1–C7 interlock chain; dual-path anti-islanding; sync-check on every close	<2s per IEEE 1547; <160ms typical with relay hardware
Diesel Optimization	Smart DG start/stop; light-load shutdown; load-following dispatch	20–48% diesel reduction (deployment-dependent)
Regulatory	IEEE 1547 / UL 1741 SB architecture; utility-accepted documentation	Accepted by SDG&E, Rule 21 territory
Auditability	Full event log: trip / close / mode change / parameter change	Utility-grade traceability on every action
Deployment Speed	Factory pre-configured and FAT-tested; plug-and-play on arrival	<1 day to first strategy activation

Section 02

System Architecture

2.1 Five-Layer Architecture

Layer	Name	Function	Key Component
L1	Strategy Engine	15 parametric modules; OTA-activated; version-locked	Strategy module library
L2	Control Core (LRE)	Real-time BESS/PCS/DG/breaker dispatch with closed-loop DI feedback	Local Runtime Engine
L3	Communication Layer	Modbus TCP, RS485, hardwired DO/DI, MQTT, WebSocket, REST API	Industrial switch, I/O board
L4	UI & Audit	HMI + remote browser UI; every action logged with timestamp and source	7"/10" touchscreen or web
L5	Security & OTA	SN-bound licensing; digital signature on every OTA push; tamper-proof logs	License engine, cloud OTA

2.2 Control Philosophy (Immutable)

Protection Trip = Relay Primary // relay owns protection; EMS observes and logs only Operational Trip = EMS Optional // controlled disconnection for commissioning/maintenance only Breaker Close = EMS Exclusive // no blind close; no auto-reclose by default Close Gate = C1–C7 All Met // all 7 conditions must be satisfied simultaneously Feedback = Physical 52a/52b // completion confirmed by hardware DI, not by command issuance Comm Timeout = Safe Frozen State // Modbus loss ≥5s → freeze setpoints, invalidate C1, P1 alarm PCS Island Mode = Grid-Forming // EMS commands mode-switch before island; verifies confirmation SOC Threshold = ±2% Hysteresis // deadband prevents charge/discharge oscillation Priority Order = Safety > Protection > Grid > Storage > Economy

⚠

Responsibility separation is fundamental. Relay settings, coordination studies, and fault-current analysis remain with the site protection engineer. EnergizeOS™ holds control and supervisory responsibility only.

2.3 Grid-Forming vs. Grid-Following

The most commonly misconfigured parameter in BESS/microgrid commissioning. EnergizeOS™ explicitly manages PCS operating mode as part of every island transition.

PCS Mode	When Active	V/f Reference	EMS Action
Grid-Following	Grid-connected	Utility sets V and f; PCS injects current	Normal dispatch via Modbus setpoints
Grid-Forming	Islanded	PCS establishes V and f for island bus	Issues mode-switch on island; verifies confirmation within 2s; P1 alarm if fails
Grid-Forming + Droop	Multi-PCS island	Each PCS shares load via P-f and Q-V droop	Configures droop parameters; monitors f deviation for instability

⚠

Critical SAT verification required: Grid-forming mode must be tested under load during SAT. A PCS left in grid-following mode cannot island. This failure is silent during grid-connected operation and only discovered at the first actual outage.

Section 03

Hardware Platform

Specification	ECP Lite	ECP Pro	OEM Embedded
Deployment	Indoor / lab	Outdoor / industrial / container	Embedded in client BESS panel
Enclosure	300×400×150 mm	800×600×250 mm	Per OEM spec
DO / DI	4× DO · 6× DI	8× DO · 10× DI	Expandable board
Ethernet	2× Industrial	4× Industrial	Modbus TCP / CAN / USB
RS485	1× Channel	2× Channels	Per OEM spec
UPS	Built-in · 7 Ah optional	Dual battery + UVT output	External / client
Cooling	Passive (indoor)	Active fan + temp/humidity sensor	Client-controlled
Rating	IP20 equiv.	NEMA 4 / IP55 outdoor	Per OEM panel

💡

Pro Panel is required when: the system controls PCC breaker closing, anti-islanding relay tripping, DG start/stop, or any function requiring UVT output. The Pro's 24 VDC UPS output provides fail-safe supply for UVT circuits and auxiliary relay coils.

Section 04

Strategy Engine

4.1 Module Catalogue

#	Module	Primary Function	Tier
01	TOU Arbitrage	Charge off-peak, discharge peak; multi-period tariff schedules	Core
02	Demand Charge Mgmt	Real-time peak shaving; BESS discharge below billing threshold	Core
03	PV Self-Consumption	Maximize solar self-use; zero-export or configurable limit	Core
04	Grid-Tie / Island Transition	Supervised PCC close/open; full C1–C7 interlock on every transition	Core
05	Anti-Islanding Protection	Dual-path detection (relay + meter); auto-trip; close blocked until both paths recover	Core
06	SOC Floor Enforcement	Min SOC reserve; ±2% hysteresis on all thresholds	Core
07	Battery Balancing Control	SOC equalization across parallel strings; prevents degradation	Core
08	Anti-Backfeed Protection	Prevents reverse power injection to utility at PCC	Core
09	Overload Protection	Site overload detection; BESS boost or load-shed sequence	Core
10	Emergency Shutdown (ESD)	Controlled DER shutdown; preserves breaker state and SOC	Core
11	DG Coordination	DG start/stop; light-load shutdown; load-following fuel optimization	Advanced
12	Load Following Dispatch	Dynamic BESS tracking island load; prevents frequency deviation	Advanced
13	AI Power Optimization	ML-based predictive scheduling via load and price forecasting	Advanced
14	Remote Override / VPP API	External setpoint override; VPP dispatch; ancillary services	Advanced
15	Flexible Strategy Triggering	User-defined logic; SDK-accessible trigger framework	Advanced

4.2 Control Priority Hierarchy

Priority	Class	Examples	Behavior
P1 Safety	Emergency — protects personnel and equipment	ESD, thermal runaway, UVT, manual stop	Overrides all lower-priority immediately
P2 Protection	Anti-islanding, anti-backfeed, overload	Modules 05, 08, 09; relay response	Overrides grid strategy; blocked only by P1
P3 Grid Compliance	IEEE 1547 operational limits	V/f ride-through, ramp rates, export limits	Overrides economic dispatch; cannot be disabled
P4 Storage Mgmt	SOC floor, balancing, thermal limits	Modules 06, 07; BMS alarm response	Limits economic dispatch; SOC floor blocks discharge
P5 Economic	Revenue-optimizing strategies	TOU (01), Demand (02), PV (03), AI (13)	Lowest; operates only within P1–P4 constraints

4.3 C1–C7 Breaker Close Interlock Chain

Code

Condition

Technical Definition

Data Source

Grid Stable ≥ 60 s

V ∈ [210–260 V]; f ∈ [59.5–60.5 Hz] both in range continuously for 60 s

Anti-islanding relay / meter

Zero Export Verified

Active power < ±50 W; no reverse injection to utility PCC

Revenue-grade meter (Modbus)

BESS Idle or Charging

PCS state = Idle or Charging; no active discharge setpoint

PCS status register

Close Authorized

Administrator confirmed via UI; role and session verified

UI role and session module

Phase Sync Completed

Phase angle ≤ 5° between island bus and utility; sync relay confirmed

Sync-check relay DI (hardwired)

Breaker Currently Open

52b auxiliary contact = OPEN confirmed via hardwired DI

Breaker 52b DI (hardwired)

Admin Role Verified

Active session = Administrator; operator-level close rejected

UI role module

⚠

If any single C1–C7 condition is not satisfied, the Close button is locked, an advisory identifies the blocking condition, and the event is logged with timestamp and state. No close command is issued to the DO output.

4.4 Communication Watchdog & Fallback

Device	Timeout	Fallback Action	Alarm
Revenue Meter	5 s	Freeze last valid reading; invalidate C1/C2; block any new close	P1 Critical
BESS / PCS	5 s	Freeze last dispatch setpoint; disable new charge/discharge commands	P1 Critical
Anti-Islanding Relay	10 s	Grid status = UNKNOWN; block all close operations	P1 Critical
DG Controller	10 s	Assume DG at last known state; disable remote start/stop	P2 Warning
Cloud / OTA Platform	No impact	All local strategies continue unaffected	P3 Info

4.5 SOC Boundary Hysteresis

Threshold	Default	Hysteresis	Behavior
SOC Floor	20%	±2%	Discharge stops at 20%; cannot resume until SOC ≥ 22%
SOC Ceiling	90%	±2%	Charge stops at 90%; cannot resume until SOC ≤ 88%
DG Start Threshold	30%	±3%	DG starts at ≤ 30%; stop not permitted until SOC ≥ 33%
Island-Enable	25%	±2%	Island only when SOC ≥ 25%; disabled if drops below 23% during island

Section 05

Protection, Redundancy & Fail-Safe

5.1 Dual-Path Anti-Islanding

Path	Hardware	Detection	Trip Execution
Path A (Primary)	Dedicated relay (ABB CM-UFD, SEL-700G)	V deviation; f out-of-range; ROCOF; anti-islanding algorithm	Direct hardwired to breaker trip coil — no EMS software in trip path
Path B (Secondary)	Revenue-grade meter (Modbus TCP)	Voltage presence; current direction; active power direction	EMS operational trip via DO — software path, secondary to relay

5.2 Triple-Redundant Trip Architecture

Method	Source	Principle	Independence
EMS DO Signal	Strategy logic	Condition-verified; full interlock enforced; logged	Powered via UPS; independent of external AC supply
UVT (Undervoltage Trip)	UPS DC bus collapse	Passive hardware; trips on UPS voltage drop; zero software required	Pure hardware — safe even if EMS software fails
Manual Field Button	Local panel button	Hardwired to trip coil; always available	Independent of all digital control and comms

5.3 Thermal Runaway Response

BMS Alarm	Condition	EMS Response	Time
Warning	Cell temp > 45°C	Derate dispatch 50%; raise P2 alarm	< 2 s
Fault	Cell temp > 55°C or BMS fault flag	Immediate BESS ESD; trip PCC if islanded; P1 alarm	< 500 ms
Thermal Runaway	BMS thermal runaway or smoke sensor	Emergency shutdown all DERs; trip all controllable breakers; lock out restart	< 200 ms

5.4 Abnormal State Handling

Event	EMS Response	Notification
Cloud / Network Loss	All strategies continue locally	"Offline Mode — Local Operation Active"
UPS Power Loss	UVT trips PCC; safe-open state	P1 red alert + event log
SOC Below Floor	Island disabled; BESS standby; load-shed	Event log + strategy mode switch
Breaker Close Failure	DO re-evaluated; 52a/52b vs. meter cross-checked; failure logged	Specific cause displayed; Close locked
Stale Measurement	C1/C2 invalidated; close blocked	"Measurement Unavailable — Close Blocked"
OTA Signature Failure	Update rejected; current version maintained	"Invalid Signature — Update Rejected"
Breaker Position Unknown	Both 52a and 52b indeterminate; close blocked	"Breaker Position Unknown — Manual Verify"
Grid Restoration (Black Start)	C1 satisfied → verify SOC → ramp idle → phase-sync → C1–C7 close → PCS to grid-following	"Grid Restored — Reconnect Sequence Active"

Section 06

Communication & Integration

Protocol	Interface	Application	Notes
Modbus TCP	Ethernet / RJ45	BESS/PCS, PV inverter, revenue meter, DG controller	Primary; full R/W; setpoint push + state readback
Modbus RTU	RS485 (2-wire)	Legacy PCS, BMS, protection relay data	Serial; battery monitoring
Hardwired DO/DI	Terminal (24 VDC)	PCC breaker 52a/52b, DG start/stop, UVT relay, relay trip output	Not subject to software or network failure
MQTT	Ethernet / Internet	OTA platform, remote console, alarm telemetry	Optional; EMS operates fully without MQTT
WebSocket	Ethernet / Internet	Remote browser UI, live strategy status	Optional; real-time updates
RESTful API	HTTPS / LAN / WAN	SCADA, VPP, BMS dashboard	Module 14 required for write access
CAN Bus	CAN (Pro / OEM)	Advanced BMS, EV charger systems	Optional; Pro and OEM only

6.2 Compatible Devices

Category	Validated Models	Interface
Revenue Meter	eGauge 4115/4150, ABB B23, Schneider PM5300	Modbus TCP; CT/PT ratio configurable
Anti-Islanding Relay	ABB CM-UFD / PO11, SEL-700G, SEL-735	DI/DO hardwired; trip contacts to trip coil
BESS / PCS	SMA, Sungrow SG, ABB PVS-980, Schneider Conext, generic Modbus	Modbus TCP; charge/discharge setpoint
PV Inverter	SMA Sunny Tripower, Fronius Symo, Sungrow SG-RT	Modbus TCP; curtailment setpoint
DG Controller	ComAp InteliGen, Deep Sea DSE, Deif AGC	Modbus or hardwired DO; run status via DI
Protection Relay	SEL-700G, SEL-351, ABB REF615, GE F650	DI/DO for trip/close interposing

Section 07

Licensing & Commercial

Component	Model	Scope	Included
ECP Panel	One-time purchase	Per unit	Factory config + strategy templates + FAT
Local Runtime Engine	Annual license / site	Per site SN	OTA rights, logging, access control, watchdog
Core Strategies (01–10)	Included	Per site	All 10 core modules active with license
Advanced Modules (11–15)	SaaS / module / site	Per module per site	Optional; OTA-activated per subscription
OTA Cloud Service	Included	Per site	Strategy push, diagnostics, changelog

7.2 Indicative Pricing

Application	Panel	Strategy Bundle	Indicative Price
Peak Shaving + Demand Control	Lite	TOU + Demand Limit	USD 8,000–12,000
Rooftop PV + Grid-Tie	Lite	PV + Grid-Tie	USD 9,000–13,000
PV-DG-Storage Co-generation	Pro	PV + DG + TOU + Grid-Tie	USD 15,000–22,000
Campus Islanding + PV	Pro	PV + Load + Grid-Tie + Anti-Islanding	USD 18,000–25,000
Demo / Pilot	Lite or Pro	Single strategy module	From USD 6,000

✓

All prices include panel hardware, factory config, FAT documentation, 1-year software license, and OTA update rights. On-site commissioning and custom strategy development quoted separately.

Section 08

Standards & Compliance

✓

IEEE 1547-2018

DER Interconnection · US Federal

✓

UL 1741 SB

Smart Inverter · Rule 21

✓

CPUC Rule 21

California Interconnection

✓

IEC 62898

Microgrid Architecture

✓

EN 50549-1/2

Anti-Islanding · EU

✓

G98 / G99

DNO Connection · UK

✓

UL 508A

Industrial Control Panels

✓

NFPA 70E / 855

Arc Flash · ESS Fire Safety

✓

IEEE 519-2022

Harmonic Limits at PCC

✓

NEC 706 / 690 / 705

ESS · PV · Interconnection

✓

IEC 62443

Industrial Cybersecurity

✓

ISA-18.2

Alarm Management

⚠

IEEE 1547 / UL 1741 SB site compliance requires utility interconnection study, relay settings by licensed PE, and utility acceptance. These are site engineer and utility responsibilities. EnergizeOS™ provides the control architecture and documentation framework.

Section 09

Deployment & Commissioning

9.1 Factory Acceptance Test (FAT)

#	Test	Procedure	Pass Criterion
T1	Power-On Self-Test	UPS energize; rails; display boot; watchdog	All rails nominal; HMI < 60 s
T2	100% I/O Loop Test	Every DO/DI; NO/NC; continuity	All correct; zero false-state
T3	Strategy Upload	OTA push; signature validate; version lock	Active; version confirmed
T4	Comm Poll	Modbus TCP all device maps; RS485; error rate	All registers readable; zero CRC errors
T5	C1–C7 Simulation	Inhibit each condition; verify lock; verify advisory; verify log	Correct lock/unlock per condition
T6	Close Failure	Close attempt with 52b = CLOSED; verify rejection and log	Rejected; log correct
T7	Trip Simulation	Simulate relay trip via DI; verify EMS state; log source = relay	State updated; source correct
T8	UPS Loss / UVT	Remove AC; verify UVT fires; EMS safe state	UVT < 200 ms; state preserved
T9	Log Export	Export log; verify all test events with timestamps	All events; timestamps accurate

9.2 Site Acceptance Test (SAT)

#	Test	Procedure	Pass Criterion
S1	Live Modbus	Poll all field devices; verify against device displays	Registers match; zero exceptions
S2	52a/52b Live Verify	Manually operate breaker; verify DI matches at all positions	DI matches physical position
S3	Relay Integration	Simulate relay trip; verify breaker opens; log attributes to relay	Opens; source = relay; no auto-reclose
S4	Grid-Forming Mode	Island manually; verify PCS → grid-forming; measure V and f under step load	PCS confirms grid-forming; V ∈ [0.95–1.05pu]; f ∈ [59.5–60.5Hz]
S5	SOC Floor + Hysteresis	Discharge to floor; verify stops; verify no resume until floor + hysteresis	Stops at floor; no oscillation
S6	Comm Loss Fallback	Disconnect meter Modbus; verify watchdog, C1 invalid, alarm; verify recovery	Fallback < 5 s; no close during loss
S7	TOU Strategy	Configure test schedule; verify BESS dispatches per schedule; check log	Dispatch matches; no spurious alarms
S8	Demand Control	Set threshold below current load; verify BESS holds demand below threshold	Demand < threshold; response < 2 s
S9	UVT + Manual Trip	Test UVT and manual button independently; verify both trip without EMS	Both trip; EMS software state irrelevant
S10	Handover	Punch list clear; operator trained; remote access confirmed; reports delivered	Zero open items; reports signed

9.3 Alarm Priority Framework (ISA-18.2)

Priority	Response	Typical Triggers	Auto-Clear
P1 Critical	< 10 min	Comm loss to meter/PCS/relay; thermal fault; UVT trip; grid-forming fail	No — requires acknowledgment
P2 Warning	< 1 hour	SOC near floor/ceiling; DG comm loss; V-THD > 8%; demand > 90% of limit	Yes — if clears within 30 min
P3 Info	Next business day	Cloud loss; OTA update available; scheduled maintenance due	Yes — on resolution

Section 10

Case Studies

🇺🇸 PepsiCo EV Depot — San Diego, California

Client / EPCPepsiCo / Black & Veatch

UtilitySDG&E — Rule 21

BESS Scale1,000 kW / 2,000 kWh

EV Chargers56 units (L2 + L3)

EMS ConfigPro + C1–C7 + AIPP

StatusRule 21 accepted · SDG&E

28–35%

Energy bill reduction via TOU + demand control

Delivery interruptions during grid outages

<150ms

Island transition (relay hardware)

🏝 Caribbean Off-Grid Microgrid

48%

Max diesel reduction (PV penetration > 60%)

$16,100

Saved per month at $1.40/L fuel

–40%

Generator runtime reduction

🇪🇸 Madrid EV Fast-Charging Station

$130K+

Annual demand penalties avoided

22%

Electricity cost reduction

$11.2K

Saved per month

Section 11

Roadmap & Lifecycle

2024 Q4

Lite/Pro Panel Launch + Core 10 Modules

Factory FAT protocol; initial deployment

✓ Done

2025 Q2

OTA Platform + C1–C7 Chain + Full Logging

Remote commissioning; strategy version management

✓ Done

2025 Q3

Engineering Delivery Package v1.0

FAT/SAT protocols; standardized wiring documentation

✓ Done

2025 Q4

AI Power Optimization Module

ML-based load and price forecasting; adaptive scheduling

● Active

2026 Q1

OAuth2 / Webhook API for VPP + SCADA

Third-party API security framework

◑ Planned

2026 Q2

Multi-Site Console + Multilingual UI

Fleet monitoring; EN/ES/DE/FR

◑ Planned

Lifecycle Commitments

Minimum 5 years support per major version release
Minimum 3 years strategy upgrade support for all subscribed modules
Hardware supports ≥ 3 future major software versions without panel replacement
Fully standalone local runtime — no cloud dependency for real-time execution
UPS, CPU, communication modules: 5-year serviceable parts availability

Section 12

Delivery Package

Ref

Document

Content

Format

Control Philosophy

EMS control boundary, trip/close philosophy, responsibility separation

PDF / Web

Single-Line Diagram

Power topology; breaker positions; protection device locations

DWG / PDF

Control Circuit Diagram

DO/DI wiring; relay circuits; UVT / UPS trip paths

DWG / PDF

IO Mapping Document

DO/DI channel assignment; Modbus address map; signal descriptions

Excel + PDF

Cabinet Layout Drawing

Panel interior layout; DIN rail; cable entry and routing

DWG / PDF

Terminal Schedule

Full terminal connection list with wire numbers and tags

Excel

FAT Test Report

Signed checklist; results; photos; engineer signature

PDF

User Manual

Strategy config guide; UI reference; alarm descriptions; operating procedures

PDF + Web

Strategy Parameter Registry

All configurable parameters; defaults; valid ranges; engineering notes

PDF + JSON

License & Activation Package

SN-bound license file; activation instructions; OTA credentials

File package

OTA & Update Manual

Strategy update and rollback procedure; version management

PDF

Section 13

Contact & Next Steps

To request a quotation, technical consultation, site-specific documentation, or FAT demonstration, contact our application engineering team. Response within 1 business day.

Sales & Technicalinfo@energizeos.com

Supportinfo@energizeos.com

Product Overviewdocs.energizeos.com/ems

Document ReferenceSPEC-EOS-EMS-001 Rev 1.0

Issued ByEnergize Solutions Inc.

DateMay 2026

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