five-level der hierarchical architecture - xanthus...

Xanthus Consulting International

Frances Cleveland [email protected]

Five-Level DER

Hierarchical Architecture

mailto:[email protected]�


DER Architecture: Logical and Operational Hierarchical Levels


DER Management Functional Requirements • Energy

– Generate energy at any time – Generate energy at specific times to offset peak load – Store energy for later delivery – Offset local loads – Provide backup power – Modify energy output autonomously in response to local

voltage variations in order to damp voltage deviations

• Reactive power – Provide reactive power by a fixed power factor – Provide reactive power through autonomous responses

to local voltage measurements – Provide reactive power through autonomous responses

to temperature

• Frequency support – Support frequency regulation on a multi-second basis by

direct automatic generation control (AGC) commands – Support frequency regulation on a second or even sub-

second basis through autonomous modifications of energy output to counter frequency deviations

• Response to emergencies – Provide “spinning” or operational reserve so that energy

is available at short notice (seconds or minutes) – Respond to emergency conditions by riding through

voltage anomalies or only tripping off if necessary – Create microgrids to minimize the extent and length of

power outages – Provide black start capabilities

• Economic responses – Provide low cost energy – Provide low emissions energy – Provide renewable energy – Support the receipt of pricing signals for demand

response actions – Manage energy and ancillary services based on pricing

signals

• Schedules – In real-time, modify energy and ancillary service outputs

based on time-based schedules – Plan ahead for generation and storage based on

scheduled requirements

• Wide area situational awareness – Provide status and measurements on current energy and

ancillary services – Forecast status and output over hours and days for

energy and ancillary services – Provide emergency alarms and information

• Direct control via remote commands – Support turn on/turn off – Support limiting maximum generation – Support setting the power factor

• Interconnection and maintenance – Provide operational characteristics to utility at initial

interconnection and upon changes – Support updating of autonomous settings and schedules

locally – Support updating of autonomous settings and schedules

through remote communications – Testing of updates for meeting regulatory and utility

requirements, including safety


Example DER “Spaghetti” Diagram extracted from NISTIR 7628 showing the logical interactions between the DER actors (these DER actors are being harmonized with the SGAM Actors) Blue are existing logical interfaces Red are new logical interfaces

NISTIR 7628 Logical Diagram of Actors and Logical Interfaces, with DER Additions to Meet the Functional Requirements


DER Architectural Levels

• Distributed Energy Resources (DER) architectural levels : – Level 1: autonomous DER systems responding to customer

preferences and local conditions – Level 2: the customer DER management systems (CDEMS)

managing local DER systems – Level 3: the retail energy providers (REP) systems and utilities

interacting with CDEMS and DER systems (multiple scenarios) – Level 4: the utility DER management systems (DERMS) to model

and analyze DER system impacts and capabilities, in order to request/command DER actions

– Level 5: the Independent System Operators (ISOs)/Regional Transmission Operators (RTOs), and the various wholesale and retail energy markets, working with the distribution utilities to provide optimization requests, pricing information, and emergency commands


Market

Enterprise

Operation

Station

Field

Process

Transmission Energy Market Clearinghouse

ISO/RTO/TSO Balancing Authority

Hierarchical DER System Five-Level Architecture, in SGAM Format

Level 4: Distribution Utility Operational Analysis and Control for Grid Operations

DER Management System (DERMS)

Distribution Management

System (DMS)

Outage Management

System (OMS)

System to Establish Demand

Response (DR) Pricing

Transmission Bus Load

Model (TBLM)

“DER SCADA” System for Control &

Monitoring

Utility Grid

Facilities Site Loads

Circuit breaker

Meter and PCC

Level 2: Facilities DER Energy Management System (FDEMS)

Level 1: Autonomous cyber-physical DER systems

Level 5: Transmission and Market Interactions

Facilities DER Energy Management Systems

(FDEMS)

Facilities Site WAN/LAN

Utility WAN/LAN


(FDEMS)

Facilities DER and LoadEnergy Management

System

PV Equipment

Electric Vehicle

PV Controller Electric Vehicle Supply Equipment

Battery Storage

Controller

Battery Diesel Generator

Diesel Controller

Distributed Energy Resources (DER) Customer PremisesTransmission Distribution

ECP ECPECPECP

Geographic Information

System (GIS)

Energy Management System (EMS)

Level 3: Utility and REP Monitoring & Control WAN Communications

Retail Energy Provider (REP) and/or DER Aggregator

Demand Response

(DR) System

REP DER & Load Management

System

Facilities Load Management

Distribution Energy Market Clearinghouse

Retail Energy Market Clearinghouse


Level 1: Autonomous Cyber-Physical DER Systems in a Customer or Utility Site

No external communications are involved, just internal communications

between the controller and the physical device

Communication Protocols and Associated Cybersecurity Standards:• Proprietary protocols – Unknown cybersecurity• Modbus – No associated cybersecurity• BACnet – Cybersecurity left up to implementers• ANSI C12.19, 22 for metering – Cybersecurity covered in C12 standards

• IEC 61850 mapped to MMS – Cybersecurity provided by IEC 62351-3, 4, 6• IEC 61850 mapped to DNP3 – Cybersecurity covered in IEEE 1815:2012• IEC 61850 mapped to Web Services – Cybersecurity may use WS-Secure• SEP 2.0 – Cybersecurity covered in SEP 2.0• SEP 1.x – Cybersecurity covered in SEP 1.x

Utility Grid


Circuit breaker

Meter and PCC


PV Equipment

Electric Vehicle


Battery Storage

Controller


Diesel Controller

ECP ECPECPECP


Levels 1: Communication Protocols and Cybersecurity

• For basic DER functionality: – Proprietary protocols – Unknown cybersecurity – SEP 1.x – Cybersecurity provided in SEP 1.x, but with some issues – Modbus – No associated cybersecurity – BACnet – Cybersecurity left up to implementers

• For advanced DER functionality, use the object models from IEC 61850-7-420 and IEC 61850-90-7 mapped to different protocols, including:

– IEC 61850 mapped to Manufacturing Messaging Specification (MMS) mapping in the IEC 61850-8-1 standard – Cybersecurity provided by IEC 62351

– IEC 61850 mapped to DNP3 (IEEE 1815) with the generic mapping to IEC 61850 in IEEE 1815.1, and a specific mapping to IEC 61850-7-420 and 90-7 developed by EPRI – Cybersecurity provided by IEEE 1815

– IEC 61850 mapped to Web services mapping which will be standardized in IEC 61850-8-2 and may be OPC UA, DPWS, REST, or Web Sockets – Cybersecurity provided by WS-Security, HTTPS, and other web services security

– SEP 2.0 with a draft mapping by EPRI, but pending final release of the SEP 2.0 specification – Cybersecurity provided by SEP 2.0

• For DER revenue metering – ANSI C12.19, ANSI C12.22, and other ANSI C12.xx – Cybersecurity covered in C12 standards, with

some issues – DLMS/COSEM (in Europe and other non-North American countries)


Level 2: DER Management System to Manage Groups of DER Systems

Facilities DER Energy Management Systems communicate with DER controllers to monitor, control, or request actions. May include multiple layers of DER Management systems.

Communication Protocols and Associated Cybersecurity Standards• Modbus – No associated cybersecurity• BACnet – Cybersecurity left up to implementers• SEP 2.0 – Cybersecurity covered in SEP 2.0• IEC 61850 mapped to MMS – Cybersecurity covered in IEC 62351

Utility Grid


Circuit breaker

Meter and PCC




(FDEMS)



(FDEMS)


System

PV Equipment

Electric Vehicle


Battery Storage

Controller


Diesel Controller

ECP ECPECPECP



Levels 2: Communication Protocols and Cybersecurity

• For basic DER functionality: – Proprietary protocols – Unknown cybersecurity

– SEP 1.x – Cybersecurity provided in SEP 1.x, but with some issues

– Modbus – No associated cybersecurity

– BACnet – Cybersecurity left up to implementers

– OASIS EMIX, Energy Interop – No explicit cybersecurity





– SEP 2.0 with a draft mapping by EPRI, but pending final release of the SEP 2.0 specification – Cybersecurity provided by SEP 2.0


Level 3: Utility and REP WAN ICT Interactions with DER Systems May Include hierarchical layers of DER management systems – see following scenarios

Communication Protocols and Associated Cybersecurity• IEC 61850 mapped to MMS – Cybersecurity provided by IEC 62351• IEC 61850 mapped to DNP3 – Cybersecurity provided by IEEE 1815• IEC 61850 mapped to web services – Cybersecurity provided by WS-Secure

or other web services security• OpenADR for pricing signals – Cybersecurity not explicitly identified• NAESB Req. 21 & 22 Energy Usage and 3rd Parties – Privacy provided



Monitoring

Utility Grid


Circuit breaker

Meter and PCC




(FDEMS)



(FDEMS)


System

PV Equipment

Electric Vehicle


Battery Storage

Controller


Diesel Controller

ECP ECPECPECP

Level 3: Utility and REP WAN Information & Communications (ICT)



System



Level 3a: DER Systems in Substations

Communication Protocols and Associated Cybersecurity Standards• IEC 61850 mapped to MMS – Cybersecurity covered in IEC 62351

Bid DER into the retail energy market

DER Architecture of Utility-Owned DER Systems in a Substation

Utility Grid

Battery Storage

Battery Storage

Controllers

Substation Power Equipment and Controls


Level 2: Facility DER Energy Management System (FDEMS)

Substation DER Energy Management System


ECP



Monitoring


Level 3b: DER Systems in Residences and Communities


DER Architecture for Residential and Community DER Systems

Electric Grid

Residential or Community Home Area Network (HAN)


Customer Site Load

Circuit breaker

Meter and PCC

Level 1: Autonomous cyber-physical management of DER systems

PV Equipment Electric Vehicle

PV ControllerBattery Storage

Controller

Battery

ECP ECPECP

Residential Facility DER Energy Management

Systems (FDEMS)



MonitoringLevel 3: Utility and REP WAN Information & Communications (ICT)



System

Electric Vehicle Supply Equipment


Level 3c: DER Systems in Commercial or Industrial Sites


DER Architecture of Commercial and Industrial DER Systems

Commercial or Campus Building

Electric Vehicle Parking and

Charging StationSub Meter

Utility Grid

Circuit breaker

Sub Meter and DER ECP

Industrial Load


Vehicle Charging LAN

Commercial or Campus Building LAN

Electric Grid

Customer Site Load


PV Equipment

PV Controller Battery Storage Controller

ECP ECP

Battery

Building DER Energy Management Systems EV Charging

Management Systems

Campus Facility DER Energy Management

Systems (FDEMS)

Microgrid DER Energy Management Systems

Electric Vehicle

ECP

Electric Vehicle

ECP

Sub Meter


PV Equipment

PV Controller

Battery Controller


Diesel Controller

ECP ECPECP

Main Meter and DER PCC

Sub Meter

Campus Microgrid



Monitoring


Retail Energy Provider (REP) and/or DER

Aggregator


System




Level 3d: DER Power Plants


DER Architecture of DER Power Plants

Wind Turbines

Wind Power Plant

Many DER Electrical Connection Points (ECPs)

Utility GridMain Meter and

Plant PCC


Storage to Counter Rapid Changes in

Wind Power

Plant DER Energy Management Systems



MonitoringLevel 3: Utility and REP WAN Information & Communications (ICT)



System


Level 3e: DER Virtual Power Plants (VPP)


DER Architecture of Virtual DER Power Plants (VPP)

Utility Grid

Many DER Electrical Connection Points (ECPs)

Virtual Power Plants

Multiple types of DER systems

located in different areas


Utility Grid

Virtual Plant DER Energy Management Systems




System


Level 3f: Military Base Microgrids with DER Systems


DER Architecture of Military Bases with DER Systems


Military Base



Utility Grid

Circuit breaker


Military Load



Military Building LAN

Military Grid

Military Site Load


PV Equipment


ECP ECP

Battery

Building DER Energy Management System

EV Charging Management System

Military Facilities DER Energy Management

Systems (FDEMS)

Microgrid Energy Management Systems

Electric Vehicle


ECP

Electric Vehicle

ECP

Sub Meter


PV Equipment

PV Controller

Battery Controller


Diesel Controller

ECP ECPECP

Main Meter and DER PCC

Sub Meter

Military Islanded Microgrid

Military Financial Microgrid




Monitoring


Level 3g: Microgrid Architecture Microgrid Architecture

Building



Utility Grid

Circuit breaker


Sub microgrid

Load



Building LAN

Electric Grid

Building Site Load


PV Equipment


ECP ECP

Battery

Building DER Energy Management Systems EV Charging

Management Systems

Microgrid Energy Management System

(microEMS)

Sub Microgrid Energy Management Systems

Electric Vehicle

ECP

Electric Vehicle

ECP

Sub Meter


PV Equipment

PV Controller

Battery Controller


Diesel Controller

ECP ECPECP

Main Meter & Microgrid Breaker

at PCC

Sub Meter



Monitoring


Retail Energy Provider (REP) and/or DER

Aggregator


System



Microgrid Breaker


Level 3: Communication Protocols and Cybersecurity





– OpenADR for demand response – No explicit cybersecurity – OASIS EMIX, Energy Interop – No explicit cybersecurity

• Customer Energy Usage provided to Third Parties – NAESB Req.18 for energy usage models – No explicit cybersecurity – NAESB Req.21 for requirements for Third Party access – No explicit cybersecurity – NAESB Req.22 for privacy for Third Party access – No explicit cybersecurity other than

the privacy


Level 4: Utility Operational DER Management: DERMS Analysis of power system requirements for safety, reliability, and efficiency, as well as price

Communication Protocols and Associated Cybersecurity Standards• IEC 61968/ 61970 (CIM) mapped to OPC UA (IEC 62541) –

Cybersecurity covered in IEC 62541• MultiSpeak – Cybersecurity provided in MultiSpeak ver. 4• XML-based enterprise standards (HTML/ HTTP, EMIX,

OpenGIS)• Application-specific protocols




System (DMS)

Outage Management

System (OMS)




Model (TBLM)


Monitoring

Utility WAN/LAN


System (GIS)


Level 4: Communication Protocols and Cybersecurity

• Enterprise application-to-application interactions using the Common Information Model (CIM)

– IEC 61968 for application-to-application messaging, such as between: • GIS and DMS • DMS and DERMS • OMS and DERMS • DR and DMS • DR and DERMS

– IEC 61970 for exchanges of power-flow models of the distribution system, including DER systems

– No explicit cybersecurity, but could use IEC 62541 (OPC UA) or WS-Security or other security for XML-based interactions

• MultiSpeak for similar application-to-application messaging – Cybersecurity provided by MultiSpeak ver. 4

• XML-based enterprise standards (HTML/ HTTP, EMIX, OpenGIS) – No explicit cybersecurity, but could use IEC 62541 (OPC UA) or WS-Security or other security for XML-based interactions

• Application-specific protocols – No explicit cybersecurity • Pricing signals:

– OpenADR, EMIX, and/or Energy Interop may be used for issuing pricing signals to CDEMS or larger DER systems – No explicit cybersecurity but could use WS-Security


Level 5: ISO/RTO/TSO Interactions

Transmission Energy Market Clearinghouse

ISO/RTO/TSO Balancing Authority




System (DMS)

Outage Management

System (OMS)




Model (TBLM)


Monitoring

Utility Grid


Circuit breaker

Meter and PCC



Level 5: Transmission and Market Interactions


(FDEMS)


Utility WAN/LAN


(FDEMS)


System

PV Equipment

Electric Vehicle


Battery Storage

Controller


Diesel Controller

ECP ECPECPECP


System (GIS)

Energy Management System (EMS)



Demand Response

(DR) System


System


Distribution Energy Market Clearinghouse

Retail Energy Market Clearinghouse


Mapping communication standards and their corresponding cybersecurity standards to the different DER interconnections

These include IEC standards as well as other standards

Communication Protocols and Associated Cybersecurity for the DER Domain


Core Smart Grid Standards Used by Utilities for DER Management and Other Functions


Customer-focused Smart Grid Standards used for Interacting with DER Systems


IEC TC57 Architecture of Standards as Basis for IEC 62351 Series of Cybersecurity Standards (shown in IEC 62351-10)


Example of Security Profile for DER using IEC 61850 Communications


Phased Implementation


Phased Approach for Reaching the Ultimate Integration of DER Systems with Utility Operations

Autonomous DER operations Expanded

Monitoring & Control

Combined Field and Virtual Modeling and

Analysis Partial

Integrated Operations

Ultimate fully integrated operations

Phase 1 Phase 3 Phase 2 Integration

Phases: 1) Start with autonomous DER systems which provide volt/var management, low/high voltage ride-through, responses to frequency anomalies, etc. Use interconnection agreements to ensure appropriate autonomous settings. 2) Expand to situational awareness with hierarchical communication networks, monitoring aggregated smaller DER and direct monitoring of larger DER. Issue broadcast requests (pricing signal and/or tariff-based) and/or direct commands 3) Combine field and virtual modeling through power flow-based analysis, state estimation, contingency analysis, and other analysis applications to assess economics and reliability. 4) Ultimately integrate DER management with distribution automation, load management, and demand response for optimal power system management.


Benefits of DER Systems


Benefits of DER to Customers #1 • Provide cost-savings for customers:

– Through net metering, feed-in tariffs, and other tariffs, to reduce overall electricity usage and costs

– Through reducing load by increasing generation in reaction to prices in Demand Response programs

– Directly through direct market participation and/or dynamic pricing tariffs

• Provide emergency backup generation – Customers can install DER for emergency power to their

critical loads – Customers can sell emergency power into a microgrid island

which was formed due to a loss of utility power


Benefits of DER to Customers #2 • Optimize energy usage through combined generation,

storage, and load management – Use DER Energy Management System to assess energy

needs over specific time frames, and schedule energy generation and energy usage

• Use by-products from customer industrial processes to generate and sell electricity: – Use heat to generate electricity through Combined Heating

and Power (CHP) systems, thus off-setting some of the customer’s costs.

– Provide biomass as source of gas, production of hydrogen as transportable energy.

• Participate in carbon trading: – If and when carbon trading becomes a reality, customers can

“trade” their low-carbon DER generation


Benefits of DER to Customers #3 • Provide combined or shared cost-savings for both utilities

and customers: – Through net metering, to reduce overall electricity usage and costs – Through different types of tariffs – Through Demand Response pricing signals – Directly through direct market participation and/or dynamic pricing

tariffs – Indirectly through overall lower electricity costs due to utility gains in

efficiency


Benefits of DER to Distribution Utility Operations #1

• Increase reliability – Provide spinning or operational reserve for local areas

– Support intentional islanding for campuses, housing developments, and industrial/commercial areas if normal energy supply is not available

• Decrease costs – Defer construction of distribution facilities through DER generation,

which acts as negative load, provides peak shaving, and supports voltage and VArs on the feeder

– Directly control DER generation to provide peak shaving to minimize start-up of costly peaker generation

– Use Demand Response or market incentives to increase DER generation during peak times

• Improve power quality – Provide smooth transitional VAr support in place of switched

capacitor banks to minimize harmonics


Benefits of DER to Distribution Utility Operations #2

• Increase generation capacity / decrease load: – Provide energy within a substation for local generation

– Provide energy from “real” and “virtual” power plants

• Improve energy efficiency: – Provide energy close to loads, thus minimizing losses

– Provide voltage support along feeders in place of voltage regulators, so that voltage levels from the feeder substation could be lowered, while still remaining within the nominal limits

– Provide VAr support to improve power efficiency

– Support load-following of local loads to improve power efficiency

– Counteract any large non-conforming loads of the DER owner, thus providing a more stable load profile to utilities


Benefits of DER to Transmission and ISO/RTO Operations • In aggregate, support energy balancing operations by

ISO/RTOs: – Provide VAr support to transmission system

– Provide frequency support

– Provide low/high voltage ride-through

– Support ancillary services required by the balancing authority

– Provide black start capabilities

• Improve energy efficiency: – Support “virtual” market-driven microgrids

– Decrease transmission losses by having generation closer to the loads


Benefits of DER for Society

• Minimize carbon and pollution production:

– Renewable DER units produce less carbon dioxide, thus helping in the battle against global climate change

– Efficient re-use of “waste heat” or other by-products of industry improve the overall efficiency of energy usage

– Many DER units, including burning biomass and CHP, can also minimize non-carbon pollutants

• Meet mandated renewable portfolios:

– Many states have legislated renewable portfolios that mandate increasing use of renewable sources of energy. Most renewables to-date are small generators

• Provide “green power” for socially conscious people

– Many people are willing to pay extra for power or to off-set their carbon “footprint”

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