distributed energy resources (der): hierarchical...

SMART GRID INTEROPERABILITY PANEL

Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the

Process for Developing Information Exchange Requirements and Object Models

A white paper developed by the Smart Grid Interoperability Panel –July 18, 2014

Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models

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Acknowledgements Frances Cleveland Al Hefner Nokhum Markushevich Hank McGlynn Wendy Al Mukdad John Nunneley Jim Reilly Other DRGS members

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http://sgip.org/wp-content/uploads/2013/04/IPR-Policy-Board-Approval-Version.pdf


Table of Contents Executive Business Summary ...................................................................................... 1 Executive Summary ................................................................................................... 5 1 Introduction ...................................................................................................... 10

1.1 Scope and Objectives of this DRGS Subgroup B White Paper ................................ 10 1.2 Background: DRGS Subgroup B on DER Use Cases, Information Exchange, and Object Models .................................................................................................................. 10 1.3 Abbreviations ........................................................................................................ 11

2 Hierarchical Architectures of DER Systems........................................................... 12 2.1 Level 1: Autonomous DER Cyber-Physical Architecture .......................................... 14 2.2 Level 2: Facilities DER Energy Management (FDEMS) Architecture ........................ 16 2.3 Level 3: Utility and/or REP Interaction Architecture ................................................. 17

2.3.1 Level 3: Generic Utility and REP Monitoring and Control of DER Systems ........... 17 2.3.2 Level 3a: DER Systems in Substations ............................................................... 19 2.3.3 Level 3b: DER Systems in Residences and Communities ................................... 20 2.3.4 Level 3c: DER Systems in Commercial or Industrial Sites ................................... 21 2.3.5 Level 3d: DER Power Plants .............................................................................. 23 2.3.6 Level 3e: DER Virtual Power Plants (VPP) ......................................................... 24 2.3.7 Level 3f: Military Bases and Microgrids with DER Systems .................................. 27 2.3.8 Level 3g: Microgrids with DER Systems ............................................................. 28

2.4 Level 4: Utility DER Management Systems (DERMS) for Operations Architecture .... 29 2.5 Level 5: DER Integration with Transmission and Market Operations Architecture ..... 31

3 Advanced DER Functions to Support Grid Operations ............................................ 33 3.1 Objectives of DER Management Functions ............................................................ 33 3.2 DER Functions for Supporting Grid Operations....................................................... 34 3.3 Advanced DER Functions ...................................................................................... 35

4 Information and Communication Technology (ICT) Requirements ............................ 38 4.1 Applicable Communication Standards .................................................................... 38

4.1.1 IEC TC 57 Standards Applied to Utility Domains ................................................. 38 4.1.2 Smart Grid Standards Used for DER Systems by Utilities .................................... 39 4.1.3 Customer-based SG Standards Used for DER Systems...................................... 39 4.1.4 Standards Expected to be Used with DER Systems ............................................ 40

4.2 Analysis of Specific Protocols ................................................................................ 41 4.2.1 IEC 61850 for DER Systems .............................................................................. 41 4.2.2 IEC 62351 for Data and Communication Security for Power Systems .................. 43 4.2.3 IEEE 1815 (DNP3) ............................................................................................ 43 4.2.4 OpenADR ......................................................................................................... 44 4.2.5 OPC/UA ............................................................................................................ 44 4.2.6 Smart Energy Profile (SEP 2.0) .......................................................................... 45 4.2.7 ANSI C12.22 ..................................................................................................... 45

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4.3 Resilience and Cybersecurity Requirements........................................................... 45 5 Categorization of DER systems and Gap Analysis of DER Use Cases ...................... 47

5.1 Approach to Identifying and Categorizing DER Systems ......................................... 47 5.2 Possible Categorizations of DER Systems ............................................................. 49

5.2.1 Categorization as Configuration of Grid Connection ............................................ 50 5.2.2 Categorization as Logical and/or Islanded Microgrids .......................................... 50 5.2.3 Categorization by Management Authority ........................................................... 50 5.2.4 Categorization by Communications Capabilities .................................................. 51 5.2.5 Categorization by DER Type and Functional Capabilities .................................... 51

5.3 List of DER Use Cases .......................................................................................... 51 5.4 Gap Analysis Process for Expanding DER Use Cases ............................................ 52

5.4.1 Selection of Use Cases ..................................................................................... 52 5.4.2 Gap Analysis Process........................................................................................ 53

6 Conclusions and Next Steps ............................................................................... 54 7 References ....................................................................................................... 55 Appendix A. Use Cases of Level 1 DER Operational Functions ...................................... 56

A.1 Real Power Use Cases ......................................................................................... 56 A.2 Reactive Power Use Cases ................................................................................... 60 A.3 Frequency Support Use Cases .............................................................................. 63 A.4 Response to Emergencies Use Cases ................................................................... 64 A.5 Economic Responses Use Cases .......................................................................... 70 A.6 Wide Area Situational Awareness Use Cases ......................................................... 71 A.7 DSO Operational and Planning Use Cases ............................................................ 72 A.8 Communications Establishment Use Cases ........................................................... 73 A.9 Registration and Maintenance Use Cases .............................................................. 74

Appendix B. Tentative List of Level 4 and Level 5 T&D Functions and Use Case Scenarios involving DER Systems ............................................................................................. 76 Appendix C. Examples of the Cross-cutting Gap Analysis ............................................. 78 Appendix D. Example of Gap Analysis for Levels 1, 2, and 3 of the DER Volt-Var Use Case.............................................................................................................................. 96 Table of Figures Figure 1: Five-Level Hierarchical DER System Architecture ............................................. 6 Figure 2: Structure of Use Cases within the DER Hierarchy ............................................. 7 Figure 3: Five-Level Hierarchical DER System Architecture ........................................... 13 Figure 4: Level 1: Autonomous DER Systems at Customer and Utility Sites .................... 15

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Figure 5: Level 2: Facilities DER Energy Management Systems (FDEMS) ....................... 16 Figure 6: Level 3: Utility/REP Monitoring and Control of FDEMS and DER Systems .......... 18 Figure 7: Level 3a: DER Systems in Substations ......................................................... 20 Figure 8: Level 3b: DER Systems in Residences and Communities ................................ 21 Figure 9: Level 3c: DER Systems in Commercial and Industrial Sites ............................. 23 Figure 10: Level 3d: DER Power Plants ...................................................................... 24 Figure 11: Level 3e: DER Virtual Power Plants (VPP) ................................................. 25 Figure 12: Information Exchange for the Coordination of VPP with Distribution

Operations ................................................................................................. 27 Figure 13: Level 3f: Military Bases and Microgrids with DER Systems ............................. 28 Figure 14: Level 3g: Microgrids with DER Systems ....................................................... 29 Figure 15: Level 4: Utility DER Management System (DERMS) for Distribution

Operations ................................................................................................. 30 Figure 16: Level 5: DER Integration with Transmission and Market Operations ................ 32 Figure 17: IEC TC 57 Standards Applicable to Different Power System Domains.............. 38 Figure 18: Smart Grid Standards Used for DER Systems by Utilities ............................... 39 Figure 19: Customer-based SG Standards Used for DER Systems ................................. 40 Figure 20: Standards Expected to Be Used with DER Systems ...................................... 41 Figure 21: Security Profile for DER using IEC 61850 Standards ..................................... 42 Figure 22: Components of Resilience of the Cyber-Physical Smart Grid .......................... 47 Figure 23: Structure of Use Cases within the DER Hierarchy ......................................... 48 Appendix B. Tentative List of Level 4 and Level 5 T&D Functions and Use Case

Scenarios involving DER Systems ................................................................. 76 Appendix C. Examples of the Cross-cutting Gap Analysis ............................................. 78 Appendix D. Example of Gap Analysis for Levels 1, 2, and 3 of the DER Volt-Var Use

Case.......................................................................................................... 96

Table of Tables Table 1: Use Cases of DER Operational Functions ....................................................... 56 Table 2: List of Secondary T&D Functions and Use Case Scenarios involving DER

Systems ..................................................................................................... 76 Table 3: Example of Use Cases vs. DER System Categories (Code definitions at end of

table) ......................................................................................................... 78 Table 4: Step-by-Step Activities vs. DER Categories (Excerpts from the Distribution Grid

Management Use Case [5])………………………………………………………...…….83 Table 5: Example of Gap Analysis for Levels 1, 2, and 3 of the DER Volt-Var Use Case

Steps……………………...…………………………………………………………………...96 Table 6: Actors vs. DER Categories (Code: r - relevant) ...…………………...……………………97 Table 7: Interfaces vs. DER Categories (Definitions of codes at the end)………………………..99

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Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models About the Smart Grid Interoperability Panel The Smart Grid Interoperability Panel (SGIP) orchestrates the work behind power grid modernization. SGIP was established to identify technical and interoperability standards harmonization that accelerates modernization of the grid. As a member-funded, non-profit organization, SGIP helps utilities, manufacturers and regulators address standards globally: utilities gain improved regulatory treatment for investment recovery and manufacturers obtain enhanced commercial opportunities worldwide. SGIP members stay competitive, informed and well-connected. To learn more about SGIP visit http://sgip.org/.

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http://sgip.org/


Executive Business Summary The landscape of the electricity sector is beginning to shift dramatically because of the increasing presence of distributed energy resources (DER). The changes are being driven by new technology, new regulations, new business models, and users’ requests for greater control and better management of their energy needs and assets. Evidence of the impact of DER—and the accompanying challenges and opportunities—can be found across the electricity sector. Here are just a few examples:

• The Edison Electric Institute (EEI), in its 2013 report, Disruptive Challenges: Financial Implications and Strategic Responses to a Changing Retail Electric Business, lists DER as a key disruptive force. The report states, “The threats posed to the electric utility industry from disruptive forces, particularly distributed resources, have serious long-term implications for the traditional electric utility business model and investor opportunities.”1

• Barclays, in May 2014, downgraded its electricity sector rating to "underweight" from "market weight," stating, "The regulatory responses to the growing competitive threat from solar + storage may prove inadequate to address potential strains to the credit profiles of issuers in these states."2

• In just one segment of the DER market (residential generation and storage), worldwide revenue from all forms of residential distributed generation and energy storage will grow from $52.7 billion annually in 2014 to $71.6 billion in 2023, according to a June 2014 report from Navigant Research.3

As these significant changes arrive, it is essential that decision-makers have both a big picture of the overall evolving DER landscape and a more detailed understanding of the possible challenges and opportunities that could affect their stakeholder organizations. This SGIP white paper, developed by the Distributed Renewables, Generation, and Storage (DRGS) Domain Expert Working Group, has the goal of developing a methodology for categorizing the vast number of DER use cases in order to better understand these challenges and opportunities for the different stakeholders. This categorization will help coordinate the communication requirements across the different DER scenarios, which in turn will enhance the interoperability of DER information exchanges in the Smart Grid.

1 Edison Electric Institute, “Disruptive Challenges: Financial Implications and Strategic Responses to a Changing Retail Electric Business,” http://www.eei.org/issuesandpolicy/finance/Documents/disruptivechallenges.pdf 2 http://www.businessinsider.com/barclays-downgrades-utilities-on-solar-threat-2014-5 3 http://www.navigantresearch.com/research/residential-energy-innovations

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http://www.eei.org/issuesandpolicy/finance/Documents/disruptivechallenges.pdf

http://www.businessinsider.com/barclays-downgrades-utilities-on-solar-threat-2014-5

http://www.navigantresearch.com/research/residential-energy-innovations


This DRGS white paper will be of interest across a broad group of domestic and international stakeholders in the Smart Grid—from utilities, manufacturers, and energy service providers to academic researchers, regulators, and consumer and public interest groups. In addition, the white paper includes some detailed examples of how to develop information exchange requirements and object models based on the suggested categorization methodology. Next year’s extension to this white paper will expand on those examples and will thus provide needed input to Standards Development Organizations (SDOs) as they tackle the technical details for standardizing the information exchange object models. The authors of this paper are technical experts from government, industry, and academia who serve on the Smart Grid Interoperability Panel’s Distributed Renewables, Generation & Storage (DRGS) Domain Expert Working Group, Subgroup B, Use Cases, Information Exchange, and Object Models. They approach the subject in a structured way that provides flexibility for a range of possibilities and yet provides a disciplined approach for the here and now.

The paper includes an executive summary, 7 sections, 4 appendices, 23 figures, and 7 tables. Section 1: Introduction (2 pages) The introduction outlines the scope and objectives of the white paper, as well as the scope of Subgroup B itself.

Section 2: Hierarchical Architectures of DER Systems (22 pages) The prevalence of DER systems throughout the electricity sector is significantly expanding—from substations, distribution feeders, real and virtual power plants, and microgrids to residences, industrial facilities, campuses, and military bases.

DER systems, at the local level, can currently manage their own generation and storage activities autonomously, based on local conditions, pre-established settings, and DER owner preferences, thus contributing to the efficiency and reliability of the distribution operations. However, as sources of energy and advanced voltage and frequency functions, DER systems must also become active participants in grid operations and must be coordinated with other DER systems and distribution grid devices to increase even more the efficiency and resilience of power system operations.

In order to encompass DER configurations and functions across all segments and domains of the Smart Grid, this section of the white paper lays out a hierarchical structure and architecture. This five-level hierarchy offers an organized approach that allows utilities and other stakeholders to interact with the thousands, if not millions, of DER systems widely dispersed in the field.

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Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models The hierarchical approach outlined in this paper can be described as hybrid combinations of five levels across multiple domains. The five levels are:

Level 1: Autonomous cyber-physical DER systems Level 2: Facilities DER Energy Management System Level 3: Utility and Retail Energy Provider Information and Communications

(ICT) Level 4: Distribution Utility Operational Analysis and Control for Grid

Operations Level 5: Transmission and Market Interactions (including Retail Energy

Provider and/or DER Aggregator) Also in this section, the authors create DER architecture diagrams that are mapped to the European Smart Grid Architectural Model (SGAM) format. The 13 figures included in this section cover the range of different configurations and DER management infrastructures. Section 3: Advanced DER Functions to Support Grid Operations (4 pages) In Levels 1 through 3, the DER systems serve the energy generation and storage needs of the owners and local operations, but the DER systems can also provide many advanced functions to support the broader grid operations. The types of DER functions are described in Section 3 and Appendix A, “Use Cases of Level 1 DER Operational Functions.” The list of 46 functions includes:

• Real power functions • Reactive power functions • Frequency support • Response to emergencies • Economic responses • Wide area situational awareness • Schedules • Communications and cybersecurity • Interconnection and maintenance

In Levels 4 and 5, the DER systems are involved in the advanced Distribution Management Systems (DMS) and Energy Management Systems (EMS) functions. A tentative list of 36 such functions is presented in Appendix B, “Tentative List of Level 4 and Level 5 T&D Functions and Use Case Scenarios Involving DER.” These functions fall into the general categories of planning, monitoring, analysis, and central control.

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Section 4: Information and Communication Technology (ICT) Requirements (12 pages) Information and communications are becoming increasingly important for monitoring and controlling the vast number of DER Systems. This monitoring and control will be managed primarily through the hierarchical infrastructures, and will involve many different information and communication technologies. This section reviews applicable communication standards; analyzes a number of specific protocols; and discusses requirements for cybersecurity and resilience.

Section 5: Categorization of DER systems and Gap Analysis of DER Use Cases (7 pages) Not only are there many variations on the hierarchical architectures and on the types and sizes of DER systems (as discussed in Section 2), DER systems can also be engineered to provide many different functions that can support grid operations (as discussed in Section 3). Combinations of these different possibilities lead to thousands of different scenarios or use cases. Because attempting to develop an exhaustive list of all possible use cases is infeasible, the next approach is to categorize the different types, configurations, purposes, and management structures of DER systems so that sample use cases can be identified by selecting representative use cases from these categories. Section 5 describes how DER system use cases may be categorized by DER Level (i.e., Levels 1 through 5) and by the purposes they support (e.g., interconnection; analysis and studies; operations; and update and maintenance). The authors then describe a 10-step process for expanding use cases and using those categorizations to determine whether DER use cases have covered all appropriate categories. This process can be used to determine if gaps still exist in international standards.

Appendices C and D provide some high-level examples for using these categories to analyze DER use cases. The actual work of identifying gaps in international standards based on the methodology suggested in the paper is being undertaken in the follow-on activities of the DRGS Domain Expert Working Group. Section 6: Conclusions and Next Steps (1 page) After very briefly summarizing the topics discussed in the paper, the authors recommend that the next phase of this work will be to complete the gap analysis for some example DER use cases as a proof of concept. The results will then be submitted to the appropriate international standards development bodies for their use in filling the gaps in their standards.

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Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models Section 7: References (1 page) Appendix A: Use Cases of Level 1 DER Operational Functions (14 pages) Appendix B: Tentative List of Level 4 and Level 5 T&D Functions and Use Case Scenarios involving DER Systems (2 pages) Appendix C: Examples of the Cross-cutting Gap Analysis (29 pages) Appendix D: Example of Gap Analysis for Levels 1, 2, and 3 of the DER Volt-Var Use Case (1 page)

Executive Summary Scope and Objectives: This white paper was developed by SGIP Distributed Renewables, Generation & Storage (DRGS) Domain Expert Working Group, Subgroup B, Use Cases, Information Exchange, and Object Models. The scope and objectives of this white paper are to enhance the interoperability of Distributed Energy Resources (DER) information exchanges in the Smart Grid via the following:

• Provide information to the power industry stakeholders on the DER hierarchical architecture, variations in DER configurations, and DER functions.

• Create DER architecture diagrams that are mapped to the European Smart Grid Architectural Model (SGAM) format, and cover the range of different configurations and DER management infrastructures.

• Develop categories of DER use cases based on the configuration of DER grid connections, DER roles in logical and/or islanded microgrids, the kind of authority for DER management, the range of communications capabilities, and the DER types and their functional capabilities.

• Describe the process for expanding the key use cases at each of the five hierarchical architecture levels to include all pertinent categories. These expanded use cases can then be used to identify information exchange gaps in international standards.

Hierarchical Architectures: Direct control by utilities is not feasible for the thousands, if not millions, of DER systems “in the field,” so a hierarchical approach is necessary for utilities to interact with these widely dispersed DER systems. At the local level, DER systems must manage their own generation and storage activities autonomously, based on local conditions, pre-established settings, and DER owner preferences. However, as sources of energy and advanced voltage and frequency functions, DER systems are active participants in grid operations and must be coordinated with other DER systems and distribution grid devices. In addition, the distribution utilities must interact with regional transmission organizations (RTOs) and/or independent system operators (ISOs) for reliability and market purposes. In some regions, retail energy providers (REPs) or other energy service providers (ESPs) are responsible for managing groups of DER systems either directly or through financial incentives and pricing signals.

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This hierarchical approach can be described as hybrid combinations of five (5) levels across multiple domains, as illustrated in Figure 1, Five-Level Hierarchical DER System Architecture, and described in Section 2.

Figure 1: Five-Level Hierarchical DER System Architecture

Advanced DER Functions to Support Grid Operations: DER systems in Levels 1 through 3 can also provide many advanced functions to support grid operations. The types of DER functions are described in Section 3 and Appendix A, Use Cases of Level 1 DER Operational Functions, and that list includes:

• Real power functions • Reactive power functions • Frequency support • Response to emergencies • Economic responses • Wide area situational awareness • Schedules • Communications and cybersecurity • Interconnection and maintenance

Market

Enterprise

Operation

Station

Field

Process

Transmission Energy Market Clearinghouse

ISO/RTO/TSO Balancing Authority

Hierarchical DER System Five-Level Architecture, Mapped to the Smart Grid Architecture Model (SGAM)

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 Manage Demand Response

(DR) Pricing Signals

Transmission Bus Load

Model (TBLM)

“DER SCADA” System for Control &

Monitoring

Utility Grid

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

Facilities DER and LoadEnergy Management

System

EV DER ControllerPV

Controller

PV Equipment

Diesel Controller

Distributed Energy Resources (DER) Customer PremisesTransmission Distribution

ECP ECPECPECP

Geographic Information

System (GIS)

Energy Management

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

Level 5: Retail Energy Provider (REP) and/or

DER Aggregator

Demand Response

(DR) System

REP DER & Load Management

System

Distribution Energy Market Clearinghouse

Retail Energy Market Clearinghouse

IEC 61850 over ModBus or SEP 2

Market information

IEC 61850 over ModBus

CIM

IEC 61850 over DNP3

IEC 61850 over ??

IEC 61850 over ??

Battery Equipment

Battery Storage Controller

Electric Vehicle Equipment

Diesel Generator


(FDEMS)

Facilities Load Management

Facilities Site Loads

Market information in OpenADR

CIM or ICCP

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Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models In Levels 4 and 5, the DER systems are involved in the advanced Distribution Management Systems (DMS) and Energy Management Systems (EMS) functions. A tentative list of such functions is presented in Appendix B, Tentative list of Level 4 and Level 5 T&D functions and use case scenarios involving DER. Information and Communication Technologies (ICT): Information and communications are becoming increasingly important for monitoring and controlling the vast number of DER Systems. This monitoring and control will be managed primarily through the hierarchical infrastructures, and will involve many different information and communication technologies. These ICT technologies are discussed in more detail in Section 4. Categorization of DER Use Cases: Not only are there many variations on the hierarchical architectures and on the types and sizes of DER systems, DER systems can also be engineered to provide many different functions that can support grid operations. Combinations of these different possibilities lead to thousands of different scenarios or use cases. It is not only impractical to enumerate all of these possible use cases, it is also likely not very useful. Therefore, it is more useful to categorize the different types of use cases, and then select representative examples from each category to expand upon. As described in Section 5, DER system use cases may be categorized by DER Level and by the purposes they support. These categorizations may be envisioned as shown in Figure 2, Structure of Use Cases within the DER Hierarchy.

Figure 2: Structure of Use Cases within the DER Hierarchy

ISO/RTO: Assess economic needs of

transmission

ISO/RTO: Assess reliability needs of

transmission

DSO: Determine economic settings

for DERs

DSO: Determine reliability settings

for DERs

DSO: Determine market prices for DER capabilities

DSO: Study and plan for DER

interconnections

FDEMS: Update autonomous

settings

FDEMS: Monitor and control

DERs

FDEMS: Manage transition & operation

of microgrid

FDEMS: Respond to

pricing signals

Hierarchical and Categorized Matrix of DER Use Cases

DSO or REP: Manage virtual

power plant

DSO or REP: Manage FDEMS in industrial sites

DSO or REP: Manage DER power plant

DSO or REP: Manage FDEMS

in residences

Level 1: DER Systems

Level 5: ISO/RTO/TSO &

Markets

Level 4: DSO Analysis &

Studies

Level 3: ICT Information &

Communications

Level 2: Facility Energy

Management

DSO: Manage DER in

substation

DSO or REP: Manage DER

microgrids

Market initiates Demand Response

request

DSO: Register nameplate info

for DERs

DERs register in market for participation in

Demand Response

FDEMS: Register DER

capabilities

Interconnection OperationsAnalysis & StudiesUpdate &

Maintenance

FDEMS: Analyze DER capabilities

DER: Real-power functions

DER: Reactive power

functions

DER: Emergency functions

DER: Frequency functions

DER: update/ maintenance

functions

DER: Development & Interconnection

FDEMS: Update &

maintenance

ISO/RTO/TSO: Command DER

services thru DSO

DSO: Establish communications

DSO: Wide area situational awareness

Categories of Functions by their Purposes

Hie

rarc

hica

l Lev

els

of F

unct

ions

DER: Testing and integration

REP: Manage DER directly at customer site

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The DER systems in the different categories may participate in various power system functions. These functions can be defined as primary (local) control functions and as secondary (central) control functions. The secondary control functions use the primary control functions as actuators. The information exchange requirements for both the primary and the secondary control functions can be represented in the use cases. Most of the primary control functions are defined in [1] and are listed in Appendix A as advanced DER functions for Level 1. A list of secondary control functions is presented in Appendix B. This list comprises the following two groups of advanced functions:

• Planning, including safety and cybersecurity requirements • Monitoring, analysis, and central control, including provision of safety and

cybersecurity

DER systems may be categorized as:

• Configuration of grid connection

• Logical and/or islanded microgrids

• Management authority

• Communications capabilities

• DER type and functional capabilities Use of Categorization for Gap Analysis: Most existing use cases involving DER were developed without addressing the specifics of all relevant DER categories, because often a use case has a specific purpose in mind. The possible combinations of use cases for power system operations with DER functions are incalculable. Multiple DER functions may be combined in different ways to create use cases with similar purposes. These use cases, in turn, may be combined with other use cases that cover different types or capabilities of DER systems, to achieve another purpose. Because attempting to develop an exhaustive list of all possible use cases is infeasible, the next approach is to categorize the different types, configurations, purposes, and management structures of DER systems so that sample use cases can be identified by selecting representative use cases from these categories. The suggested process for expanding use cases and determining the gaps in the existing use cases addressing these specifics is described in Section 5.4. The suggested process includes the following actions:

• Selecting use cases and screening them across all of the DER categories to determine if there might be gaps in the associated standards. Examples of this are presented in Table 3 of Appendix C, “Examples of the Cross-cutting Gap Analysis,, and Table 7 of Appendix D, “Example of Gap Analysis for Levels 1, 2, and 3 of the DER Volt-Var Use Case.”

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• Gap analysis of the list and contents of actors of the selected use cases for each relevant DER category. An example of this is presented in Table 4 of Appendix C.

• Gap analysis of the list and contents of step-by-step actions of the selected use cases for each relevant DER category. An example of this is presented in Table 5 of Appendix C.

• Gap analysis of the list and contents of logical interfaces of the selected use cases for each relevant DER category. An example of this is presented in Table 6 of Appendix C.

Conclusions: As stated in Section 6, this document covers the following topics:

• Describes the five-level hierarchical architecture of DER systems, including variations of configurations and management infrastructures.

• Presents advanced functions involving DER systems, associating them with different hierarchical levels.

• Discusses the need for expanding DER-related use cases to determine whether gaps exist in international standards, and states the impracticality of undertaking an exhaustive update of these use cases for all configurations, purposes, types, functions, and management techniques of DER systems.

• Develops a proposed process for managing this “big data” problem by categorizing DER systems and using those categorizations to determine whether DER use cases have covered all appropriate categories as a first step to determine if gaps still exist in international standards.

• Provides some high-level examples for using these categories to analyze DER use cases in Appendices C and D. However, the actual work of identifying gaps in international standards has not yet been undertaken.

The next phase of this work will complete the gap analysis for some example DER use cases as a proof of concept. The results will be submitted to the appropriate international standards development bodies for their use in filling the gaps in their standards.

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1 Introduction

1.1 Scope and Objectives of this DRGS Subgroup B White Paper Scope and Objectives: The scope and objectives of this DRGS Subgroup B white paper are to enhance the interoperability of DER information exchanges in the Smart Grid via the following:

• Provide information to the power industry stakeholders on the DER hierarchical architecture, variations in DER configurations, and DER functions.

• Create DER architecture diagrams that are mapped to the European SGAM format, and cover the range of different configurations and DER management infrastructures.

• Develop categories of DER systems based on the configuration of DER grid connections, DER roles in logical and/or islanded microgrids, the kind of authority for DER management, the range of communications capabilities, and the DER types and their functional capabilities.

• Describe the process for expanding the key use cases at each of the five hierarchical architecture levels to include all pertinent categories. These expanded use cases can then be used to identify information exchange gaps in international standards.

1.2 Background: DRGS Subgroup B on DER Use Cases, Information Exchange, and Object Models

The scope of the DRGS Subgroup B is defined as:

• Convene a group of experts with knowledge of the wide range of DRGS-related Smart Grid use cases; DRGS-related information exchange requirements; and DRGS- related object model development, standardization, and mapping to different communication protocols used for the Smart Grid.

• Define approaches to address specific concerns related to consistency of information models between: large and small DRGS devices; different levels of interconnection complexities between domains; and location of DER devices on feeder, type of feeder, and interaction with other DERs on the feeder.

• Assemble an inventory of the already-developed DRGS object models, sketch out a taxonomy of the interrelationships, and define a strategy for improving consistency between DRGS object models used for the Smart Grid.

Based on this scope and on subsequent efforts in the DRGS and in the International Electrotechnical Commission (IEC), a more descriptive title for this subgroup might be “Categorizing Use Cases in Hierarchical DER Architectures for Developing Information Exchange Requirements and Object Models.”

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Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models 1.3 Abbreviations

Abbreviation Definition CIM Common Information Model CVPP Commercial Virtual Power Plant DER Distributed Energy Resource

DERMS Distributed Energy Resource Management System DMS Distribution Management System DSO Distribution System Operator, distribution utility

ECP Electrical Connection Point EMS Energy Management System

ESP Energy Service Provider EV Electric Vehicle EVSE Electric Vehicle Supply Equipment

FDEMS Facility DER Energy Management System FLISR Fault Location, Isolation, and Service Restoration

GIS Geographical Information System GWAC GridWise Architecture Council ICT Information and Communication Technologies

IEC International Electrotechnical Commission ISO Independent System Operator IVVWO Integrated Volt/Var/Watt Optimization

MMS Manufacturing Messaging Specification OMS Outage Management Systems

PCC Point of Common Coupling PEV Plug-in Electric Vehicle REP Retail Energy Provider

RTO Regional Transmission Operator SCADA Supervisory Control and Data Acquisition

SEP Smart Energy Profile TBLM Transmission Bus Load Model

11


Abbreviation Definition TSO Transmission System Operator, transmission utility TVPP Technical Virtual Power Plant

VPP Virtual Power Plant WAN Wide Area Network

2 Hierarchical Architectures of DER Systems Direct control by utilities is not feasible for the thousands, if not millions, of DER systems “in the field,” so a hierarchical approach is necessary for utilities to interact with these widely dispersed DER systems. At the local level, DER systems must manage their own generation and storage activities autonomously, based on local conditions, pre-established settings, and DER owner preferences. However, DER systems are active participants in grid operations and must be coordinated with other DER systems and distribution grid devices. In addition, the distribution utilities must interact with regional transmission organizations (RTOs) and/or independent system operators (ISOs) for reliability and market purposes. In some regions, retail energy providers (REPs) or other energy service providers (ESPs) are responsible for managing groups of DER systems. This hierarchical approach can be described as hybrid combinations of five (5) levels across multiple domains, as illustrated in Figure 3, Five-Level Hierarchical DER System Architecture. The Smart Grid Architecture Model (SGAM) was originally developed by the European community under the M/490 effort. This model and the SGIP model are now actively being harmonized. For instance, the SGIP model now recognizes DER as a domain, although it has not finalized a new model diagram structure. In addition to the model, possible communication technologies and standards are also identified in the figure, although these are just examples.

12


Figure 3: Five-Level Hierarchical DER System Architecture

Level 1 DER Systems (green in the Figure) is the lowest level and includes the actual cyber-physical DER systems themselves. These DER systems will be interconnected to local grids at Electrical Connection Points (ECPs) and to the utility grid through the Point of Common Coupling (PCC). These DER systems will usually be operated autonomously. In other words, these DER systems will be running based on local conditions, such as photovoltaic systems operating when the sun is shining, wind turbines operating when the wind is blowing, electric vehicles charging when plugged in by the owner, and diesel generators operating when started up by the customer. This autonomous operation can be modified by DER owner preferences, pre-set parameters, and commands issued by utilities and aggregators. Level 2 Customer DER Management (blue in the Figure) is the next-higher level, in which a customer DER management system (FDEMS) manages the operation of the Level 1 DER systems. This FDEMS may be managing one or two DER systems in a residential home, but more likely will be managing multiple DER systems in commercial and industrial sites, such as university campuses and shopping malls. Utilities may also use a FDEMS to handle DER systems located at utility sites such as substations or power plant sites.

Market

Enterprise

Operation

Station

Field

Process



Hierarchical DER System Five-Level Architecture, Mapped to the Smart Grid Architecture Model (SGAM)




System (DMS)

Outage Management

System (OMS)




Model (TBLM)


Monitoring

Utility Grid

Circuit breaker

Meter and PCC





(FDEMS)


Utility WAN/LAN


System

EV DER ControllerPV

Controller

PV Equipment

Diesel Controller

Distributed Energy Resources (DER) Customer PremisesTransmission Distribution

ECP ECPECPECP


System (GIS)

Energy Management



DER Aggregator

Demand Response

(DR) System


System



IEC 61850 over ModBus or SEP 2

Market information


CIM

IEC 61850 over DNP3

IEC 61850 over ??

IEC 61850 over ??

Battery Equipment



Diesel Generator


(FDEMS)



Market information in OpenADR

CIM or ICCP

13


Level 3 Utility and REP WAN Communications (red in the Figure) extends beyond the local site to allow utilities and market-based aggregators and retail energy providers (REP) to request or even command DER systems (typically through a FDEMS) to take specific actions, such as turning on or off, setting or limiting output, providing ancillary services (e.g. volt-var control), and other grid management functions. REP/aggregator requests would likely be price-based focused on greater power system efficiency, while utility commands would also include safety and reliability purposes. The combination of this level and Level 2 may have varying scenarios, while still fundamentally providing the same services. Level 4 Distribution Utility Operational Analysis (yellow in the Figure) applies to utility applications that are needed to determine what requests or commands should be issued to which DER systems. Utilities must monitor the power system and assess if efficiency or reliability of the power system can be improved by having DER systems modify their operation. This utility assessment involves many utility control center systems, orchestrated by the Distribution Management System (DMS) and including the DER database and management systems (DERMS), Geographical Information Systems (GIS), Transmission Bus Load Model (TBLM), Outage Management Systems (OMS), and Demand Response (DR) systems. Once the utility has determined that modified requests or commands should be issued, it will send these out as per Level 3. Level 5 Transmission and Market Operations (purple in the Figure) is the highest level, and involves the larger utility environment where regional transmission operators (RTOs) or independent system operators (ISOs) may need information about DER capabilities or operations and/or may provide efficiency or reliability requests to the utility that is managing the DER systems within its domain. This may also involve the bulk power market systems, as well as market functions of retail energy providers. Although in general DER systems will be part of a hierarchy, different scenarios will consist of different hierarchical levels and variations even within the same hierarchical level. For instance, small residential PV systems may not include sophisticated Facilities DER Energy Management Systems (FDEMS), while large industrial and commercial sites could include multiple FDEMS and even multiple levels of FDEMS. Some DER systems will be managed by Retail Energy Providers through demand response programs, while others may be managed (not necessarily directly controlled) by utilities through financial and operational contracts or tariffs with DER owners.

2.1 Level 1: Autonomous DER Cyber-Physical Architecture At Level 1, DER generation and storage systems are operated autonomously as cyber-physical systems. They are typically installed at a customer site behind the meter. The only communications between the utility and the DER systems are the meter readings. Figure 4, Level 1: Autonomous DER Systems at Customer and Utility Sites, illustrates a typical architecture that includes PV generation, electric vehicle, battery storage, the owner’s human-machine interface (HMI), and customer load. The red line in the diagram represents the electric power grid to which the DER systems are connected at their Electrical Connection Points (ECPs) and to which they are providing power. The

14

Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models green line represents either point-to-point communications between a DER controller and a simple display or a home area network (HAN) that allows customers to set their preferences. This environment also includes the customer load (which may or may not be controllable—and is beyond the scope of this document), the circuit breaker between the customer premises and the utility grid, as well as the utility meter at the Point of Common Coupling (PCC) that measures both load and generation at that interface. Beyond the PCC is the utility grid.

Figure 4: Level 1: Autonomous DER Systems at Customer and Utility Sites

The owners of DER systems typically use them for off-setting their own loads. They may also have a contract with the utility for net metering or feed-in tariffs in which the owner’s meter measures both load and generation between the customer’s site and the local distribution grid, usually including different rates for different times of day or week. The autonomous DER settings could also include ancillary services such as volt-var control, frequency control, and low/high voltage ride-through. In most cases, the owners of DER systems must have “interconnection agreements” with the distribution utility, typically based on the IEEE 1547, Interconnecting Distributed Resources with Electric Power Systems, DER interconnection standard or similar regulations by states and countries. These agreements thus ensure that the utility is aware of the existence, identity, and general capabilities of the DER systems in their distribution grid. Each DER system can be viewed as composed of two classes of components: a physical hardware/firmware component and a cyber controller component that manages the physical component. These individual DER systems operate autonomously most of the time with the cyber controllers closely monitoring the physical devices and responding to the local electrical conditions by controlling the physical DER systems according to pre-specified settings.4 The controllers can also respond to customer preferences and to external commands to change modes or schedules, or to react to emergency situations. DER systems may be owned by customers, third parties, or utilities. They may be directly managed by the owners, or their management may be outsourced to retail energy providers or other “virtual power plant (VPP)” companies. Some DER systems may be renting space on customer premises, but owned by other companies.

4 Different types of these settings are defined in IEC 61850-90-7.

Utility Grid


Circuit breaker

Meter and PCC


PV Equipment

Electric Vehicle

PV Controller Electric Vehicle Supply Equipment

Battery Storage

Controller

Battery Diesel Generator

Diesel Controller

ECP ECPECPECP

15


Electric vehicles (EV) are a special case of DER systems when they are used to provide DER-type energy and/or ancillary services to the utility, such as limiting the rate of charging, reacting to demand response pricing information, or slowing or increasing the charging rate to counteract frequency deviations. When the inverter is located onboard the EV, the EV provides both the cyber controller and the physical equipment, consisting of the power conversion electronics and the battery. The inverter could also be located in the Electric Vehicle Supply Equipment (EVSE) with the EV only providing its battery for use by the EVSE. This DER architecture is identical to that shown for the stationary storage system with the EVSE serving as the Battery Storage Controller and the EV providing the battery.

2.2 Level 2: Facilities DER Energy Management (FDEMS) Architecture At Level 2, the DER systems are managed locally by a Facilities DER Energy Management system (FDEMS). (This FDEMS may be part of a broader Customer Energy Management System, but is focused on managing the DER systems.) The FDEMS manages a group of DER systems locally, usually within a customer site, within a substation, or within a small region such as a subdivision or community. Communications now include interactions between the DER system controllers and the FDEMS. Multiple FDEMS systems may be involved, with some operating in parallel, while others coordinate multiple smaller FDEMS. For instance, a university campus may include a “building” FDEMS for each campus building that has DER systems, but would also have one “campus” FDEMS that coordinates the many “building” FDEMS to ensure optimal energy management of the entire campus. Figure 5, Level 2: Facilities DER Energy Management Systems (FDEMS), illustrates the

Level 2 FDEMS management of multiple DER systems.

Figure 5: Level 2: Facilities DER Energy Management Systems (FDEMS)

The purpose of the DER systems managed by FDEMS may include the same types of tariffs as the autonomous DER systems, namely time-of-use net metering, feed-in

Utility Grid


Circuit breaker

Meter and PCC




(FDEMS)



(FDEMS)


System

PV Equipment

Electric Vehicle

PV Controller Electric Vehicle Supply Equipment

Battery Storage

Controller


Diesel Controller

ECP ECPECPECP


16

Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models tariffs, and pre-set ancillary services support. In addition, the DER systems may also include responding to demand response (DR) pricing signals, bidding into retail markets, and other financial programs. These financial programs could include incentives for more dynamic management of energy and ancillary services. In addition, the FDEMS may be able to create and manage electrically islanded microgrids if grid power is lost. A campus FDEMS could rapidly establish what generation requirements are needed to meet the load requirement, then take specific actions such as shutting down some loads, starting up additional DER systems such as diesel generators, and issuing the appropriate settings to each DER system so that it would operate in a coordinated manner within this much smaller microgrid. Residential FDEMSs manage the equipment connected to Home Area Networks (HAN), including PV systems and electric vehicle chargers. Commercial and industrial FDEMSs, such as those on university campuses, hospitals, shopping malls, and industrial plants, may allocate DER requirements across multiple DER systems as well as using load management in order to manage the overall customer energy profile. Power plants, including virtual power plants (VPP), also manage multiple DER systems that may be local or dispersed. A FDEMS may be viewed as a VPP management system if it predominantly manages DER systems, but it may also manage and coordinate loads and other energy-related systems within homes, buildings, campuses, and office complexes. There may also be a hierarchical set of FDEMSs, such as in a campus where a building FDEMS manages that building, while the campus FDEMS manages all of the building FDEMSs. Another hierarchy could include residential FDEMSs that are coordinated by a community FDEMS. A FDEMS has a more global vision of the multiple DER systems under its control than each DER controller could have. It understands the overall capabilities of the DER systems under its management and can allocate energy generation and storage functions to each DER system according to the overall energy efficiency and/or reliability requirements.

2.3 Level 3: Utility and/or REP Interaction Architecture

2.3.1 Level 3: Generic Utility and REP Monitoring and Control of DER Systems At Level 3, utilities and/or Retail Energy Providers (REPs) coordinate and manage DER systems from a more global perspective, based on the real-time requirements of the distribution and transmission systems, as well as the demand response pricing signals from market systems. Communications now include interactions between the FDEMS and the utility/REPs. These hierarchical DER management interactions are shown in Figure 6, Level 3: Utility/REP Monitoring and Control of FDEMS and DER Systems.

17


Figure 6: Level 3: Utility/REP Monitoring and Control of FDEMS and DER Systems

The utility “DER SCADA system” (in quotes, because this may or may not be part of a traditional utility SCADA system) and/or the REPs monitor the DER systems primarily through the DER owner’s FDEMS and issue controls to power system equipment in real-time. This includes some individual large DER systems directly, aggregations of smaller DER systems through a FDEMS or by broadcasting, and combined DER generation and loads generally located at substations. Because the necessary communications from utilities and other energy managers may involve interactions with hundreds and even thousands of DER systems, monitoring their status and output may need to rely on multiple types of communications solutions. Utilities could monitor the real-time status of DER systems through a combination of:

• Directly monitoring energy and other electrical characteristics at the “Point of Common Coupling” (PCC) for larger or more “sensitive” DER installations.

• Receiving aggregated DER data from larger FDEMS systems, such as campuses, office complexes, or industrial plants. This approach can minimize the number of access points monitored.



Monitoring

Utility Grid

Circuit breaker

Meter and PCC




(FDEMS)



System

EV DER ControllerPV

Controller

PV Equipment

Diesel Controller

ECP ECPECPECP

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


DER Aggregator


System

Battery Equipment



Diesel Generator


(FDEMS)



18


• Monitoring energy and other electrical characteristics of a feeder at a distribution substation. This approach is adequate when DER system generation only accounts for a small percentage of the total load on a relatively robust feeder.

Utilities will not generally be able to use the same types of direct control as they use for utility-owned power system equipment. For instance, they will issue broadcast or multicast commands. These broadcast/multicast messages would consist of the following:

• One-way commands for emergency situations

• Demand-response pricing signals

• Utility requests for specific DER modes

• Updated settings for autonomous DER actions (These may not be immediately acted upon, but may be set for future commands or power system conditions.)

• New schedules for DER actions in the future Variations on the configurations of these systems are discussed in the following sections and illustrated in the diagrams.

2.3.2 Level 3a: DER Systems in Substations As shown in Figure 7, Level 3a DER Systems in Substations, utilities are installing DER systems, particularly large storage systems, to help manage operations through counteracting anomalous voltage and/or frequency situations. These are usually directly controlled through SCADA systems from the utility’s operation center. For this reason, these DER systems are managed and secured just like any other substation equipment. Typical interactions could include:

• Monitoring the status of the DER system

• Directing specific generation and/or storage actions

• Setting reactive power parameters

• Controlling generation through automatic generation control (AGC)

• Initiating autonomous counteracting of voltage deviations

• Initiating autonomous counteracting of frequency deviations

• Providing additional energy during peak load periods Riding-through high/low voltage and/or frequency levels

19


Figure 7: Level 3a: DER Systems in Substations

2.3.3 Level 3b: DER Systems in Residences and Communities As illustrated in Figure 8, Level 3b DER Systems in Residences and Communities, increasingly, residential homes and communities are installing DER systems, particularly photovoltaic systems. In the future, electric vehicles will also become more common at these residential sites. Individual residential homes may or may not have actual FDEMS equipment, although DER controllers may provide some of the functionality associated with FDEMS, such as responding to external commands or pricing signals. Residential subdivisions, apartment complexes, and office buildings will require FDEMS functionality to respond appropriately to utility and REP commands, such as allocating which DER systems are to respond to which commands. Utility and REP interactions with the FDEMS systems can be one-to-one over communication networks, or can be broadcast/multicast to groups of FDEMSs. Upon installation, the DER systems associated with each FDEMS will need to be registered with the utility, and, if to be managed by a REP, registered with the REP. This registration may be handled off-line or may be handled through automated “discovery and registration” procedures.

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

Level 3: Utility and REP Monitoring & Control WAN Communications

ECP



Monitoring

20


Figure 8: Level 3b: DER Systems in Residences and Communities

2.3.4 Level 3c: DER Systems in Commercial or Industrial Sites As illustrated in Figure 9, Level 3c DER Systems in Commercial and Industrial Sites, DER systems are installed in commercial and industrial sites. These sites may have more sophisticated FDEMS systems that may be hierarchical. For instance, a university campus may have one central FDEMS that interacts with the REPs and Utility, but may also have multiple FDEMSs located in different facilities that manage the multiple DER systems within those facilities. Although not directly discussed in this document, it is expected that these FDEMSs will manage load at the same time they are managing the DER systems. The types of interactions between the REPs, utilities, FDEMS, and DER systems are also more complex, varying with configuration, the type of DER system, the needs of the DER owner, and the regulatory structure of the DER market. Examples of these interactions can include:

• The central FDEMS issues aggregate generation and storage goals to each of its facility-specific FDEMS. In turn, these facility FDEMS allocate specific actions and schedules to each DER system, and monitor compliance to these allocations. If a DER is not able to meet its allocated requirement, the facility FDEMS reassesses and updates the allocations.

• Upon receiving a pricing signal from a REP, the central FDEMS allocates the energy and ancillary service goals to each of the facility FDEMS, which in turn

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 Monitoring & Control WAN Communications

Retail Energy Provider (REP) and/or DER Aggregator


System

Electric Vehicle Supply Equipment

21


allocate these to more precise generation and storage levels to each of their DER systems.

• Upon receiving a schedule of actions from the utility, the same allocation steps are taken.

• If authorized, DER systems operate autonomously to respond to emergency situations such as voltage and frequency anomalies. These actions are reported to the facility FDEMS in audit logs and other reports.

• Upon receiving emergency commands from the utility, each FDEMS issues the appropriate command to its DER systems.

• If used for backup power, the autonomous DER systems could manage the transition from failed grid to instantaneous power for a microgrid, to sustained power for the microgrid, to expansion of the microgrid to additional facilities (in coordination with appropriate FDEMS), and/or to eventual reconnection to the main grid after power is restored.

In some cases, facility FDEMS will create microgrids. These microgrids could be “virtual” in that they act as if they are physically separated from the grid, but still do remain connected. They could also be electrically disconnected from the grid, and would balance generation and load while remaining within the required voltage and frequency ranges. In addition to normal AC microgrids, DC microgrids could be established, with a FDEMS managing the flow of energy and reactive power across the AC/DC inverter. Electric vehicle parking lots could also be managed, acting not only as modifiable load, but also as active generation when needed.

22


Figure 9: Level 3c: DER Systems in Commercial and Industrial Sites

2.3.5 Level 3d: DER Power Plants As illustrated in Figure 10, Level 3d DER Power Plants, DER systems may also be configured into power plants with the primary purpose of providing energy and possibly ancillary services to the grid. These power plants would be operated in close coordination with the distribution operations, due to their aggregated generation and/or storage capacity and to their potential for providing reliability and efficiency services to the grid. Typically, these DER power plants would be behind one or possibly two PCCs with minimal loads (e.g., auxiliary power for the Plant DER Energy Management System and local control houses). Examples of interactions include:

• Monitoring of energy and other measurements at the PCC by the utility and/or REP.

• Requests and/or direct commands sent to the Plant DER EMS for energy or ancillary services.

Updates to schedules and settings.

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



23


Figure 10: Level 3d: DER Power Plants

2.3.6 Level 3e: DER Virtual Power Plants (VPP) A virtual power plant (VPP), as illustrated in Figure 11, Level 3e DER Virtual Power Plants (VPP), aggregates the capacity of many diverse DERs, Demand Response, and Energy Storage (Megawatts and Negawatts). It creates a single operating profile from a composite of the parameters characterizing each DER, and can incorporate the impact of the network on their aggregate output. In other words, a VPP is a flexible representation of a portfolio of DER systems that can be used to make contracts in the wholesale market and to offer services to system operators. As any large-scale generator, the VPP can be used to facilitate DER trading in various energy markets and can provide both energy and ancillary services to support transmission and distribution system management.

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 Monitoring & Control WAN Communications

Retail Energy Provider (REP) and/or DER Aggregator


System

24


Figure 11: Level 3e: DER Virtual Power Plants (VPP)

The VPP’s activities in market participation, grid management, and grid support can be described respectively as “commercial” and “technical” activities, introducing the concepts of Commercial VPP (CVPP) and Technical VPP (TVPP) [1-3]. According to [1], Commercial VPP is characterized by an aggregated profile and output that represents the cost and operating characteristics of the DER portfolio. The impact of the distribution network is not considered in the aggregated Commercial VPP profile. CVPP functionality includes trading in the wholesale energy market, balancing of trading portfolios, and provision of services that are not location-specific to the system operator. The operator of a CVPP can be any third party or balancing responsible party with market access, such as an energy supplier. The basic inputs for the CVPP are as follows:

• DER inputs – Operating parameters – Marginal costs – Metering data – Load forecasting data

• Other inputs – Market intelligence (e.g., price forecasts) – Locational data/network modeling

• Based on these input data the CVPP

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



DER Aggregator


System




25


– Aggregates capacity from DER units – Optimizes revenue from contracting DER portfolio output and offering

services – Develops contracts – Develops DER schedules, parameters, and costs for TVPP [1]

The Commercial VPP can be composed of any number of distributed energy resources (located either in the same distribution network area or in different areas), and one distribution network area may contain multiple aggregated portfolios. This Commercial VPP role can be undertaken by a number of market actors including existing energy suppliers, third party independents, or new market entrants. DER owners are free to choose a Commercial VPP to represent them in the wholesale market and towards the Technical VPP. Technical VPP consists of distributed resources from the same geographic location. It is represented through an aggregated profile which includes the influence of the local network on the portfolio output and also represents the DER cost and operating characteristics. Technical VPP functionality includes local system management for Distribution System Operators (DSO), as well as providing system balancing and ancillary services to Transmission System Operators (TSO). The operator of a Technical VPP requires detailed information of the local network, so typically the TVPP operator will coordinate with the DSO. The Technical VPP provides the DSO operator with visibility of energy resources connected to the distribution network, allowing distributed generation and demand to contribute to transmission system management. Aspects of the TVPP can also facilitate the use of distributed resource capacity in the distribution networks should active network management be desirable (e.g., for FLISR and/or IVVWO). The TVPP aggregates and models the response characteristics of the power system containing distributed generation, controllable loads, and networks within a single geographical grid area, essentially providing a description of sub-system operation. A hierarchy of TVPP aggregation may be created to characterize systematically the operation of DER at low, medium, and high voltage regions of a local network. Nevertheless, at the distribution-transmission network interfaces, the Technical VPP presents a single generation-load profile representing the whole local network. This technical characterization is equivalent to the characterization that the transmission system operator has of transmission-connected generation. The basic inputs for the TVPP are as follows:

• DER inputs (provided via CVPP) – Operating schedule – Bids & Offers / marginal cost to adjust position – Operating parameters

• Other inputs – Real-time local network status

26


– Loading conditions – Network constraints

A possible information exchange between the REP and Utility is presented in Figure 12, Information Exchange for the Coordination of VPP with Distribution Operations.

Figure 12: Information Exchange for the Coordination of VPP with Distribution Operations

VPPs can also be configured across multiple distribution feeders, providing coordination with DR load management and distribution automation. VPPs can even be configured across multiple utilities (e.g., Solar City), where a municipality acts as a VPP.

2.3.7 Level 3f: Military Bases and Microgrids with DER Systems Military bases, as illustrated in Figure 13, Level 3f Military Bases and Microgrids with DER Systems, represent similar configurations as commercial and industrial facilities, but could include even more extensive combinations of DER management and dynamic creation of microgrids. For instance, a military base could require rapid transitions between grid-connected and islanded operations under different circumstances, such as emergencies and extreme weather conditions.

Commercial VPP (REP) Technical VPP DMS (Utility)

1. Initial Input

5. Corrections

2. Initial model

6. Final model

3. Constraints, requests 4. Adjustments to constraints, requests

27


Figure 13: Level 3f: Military Bases and Microgrids with DER Systems

2.3.8 Level 3g: Microgrids with DER Systems Microgrids, as illustrated in Figure 14, Level 3g Microgrids with DER Systems, are defined as combinations of DER systems and loads that could become a viable island when disconnected from the grid, but may remain connected for economic or other reasons. Microgrids could be nested, with microgrids within microgrids. Microgrids could be configured to only become islanded upon a specific command, or they could become islanded upon loss of grid power.

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

PV Controller Battery Storage Controller

ECP ECP

Battery

Building DER Energy Management System

EV Charging Management System

Military Facilities 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

Military Electric Microgrid

Military Financial Microgrid




Monitoring

28


Figure 14: Level 3g: Microgrids with DER Systems

2.4 Level 4: Utility DER Management Systems (DERMS) for Operations Architecture

At Level 4, utilities need to analyze and coordinate DER systems with distribution operations for both efficiency and reliability of the power grid. Utilities must monitor the power system and assess if efficiency or reliability of the power system can be improved by having DER systems modify their operation. This utility assessment involves many utility control center systems, including “back office” systems, asset databases, and planning systems. The real-time operations are orchestrated by the Distribution Management System (DMS) and include the DER database and management systems (DERMS), Geographical Information Systems (GIS), Transmission Bus Load Model (TBLM), Outage Management Systems (OMS), and Demand Response (DR) systems. Exactly which functions are allocated to which systems is an open issue, because handling large numbers of non-utility-owned DER systems is new for distribution utilities. Therefore, the systems shown in the diagram are just examples, and different utilities may organize their DER functions differently. Once the utility has determined that operational changes are needed, it will send these out as per Level 3 via the “DER SCADA” system that monitors and controls the DER systems (primarily through FDEMS) within the utility’s territory. This DER SCADA system may be the same as the distribution SCADA system, but could very likely be a separate system. These operational changes can be issued via direct commands, through tariff-based requests, or as demand-response pricing signals. These types of interactions are illustrated in Figure 15, Level 4: Utility DER Management System (DERMS) for Distribution Operations.

Microgrid Architecture

Building



Utility Grid

Circuit breaker


Sub microgrid

Load



Building LAN

Electric Grid

Building Site Load



ECP ECP

Battery Equipment

Building DER Energy Management Systems EV Charging

Management Systems

Microgrid Energy Management System

(microEMS)

Sub Microgrid Energy Management Systems


ECP ECP

Sub Meter


Battery Controller

Battery Equipment

Diesel Generator

Diesel Controller

ECP ECPECP

Main Meter & Microgrid Breaker

at PCC

Sub Meter



Monitoring


EV DER Controller

EV DER Controller

Microgrid Breaker

PV Equipment

PV Controller


PV Controller

PV Equipment


DER Aggregator


System

29


Figure 15: Level 4: Utility DER Management System (DERMS) for Distribution Operations

The utility DMS and DERMS, in conjunction with other distribution operations systems, perform the following functions:

• Register the location and capabilities of all DER systems and related FDEMS systems in its territory, following the interconnection processes and agreements. The locational information is added to the Geographic Information System (GIS), while the capabilities information is stored in the DERMS or in the automated mapping and facilities management (AM/FM) systems for use by other distribution functions.

• Assess the energy profiles and the ancillary services capabilities of the DER systems for each feeder section and substation from the AM/FM database. These DER profiles need to be coordinated with the corresponding load profiles, particularly as higher penetrations of DER systems become interconnected to the distribution system. This coordination will mostly likely be performed by the utility DMS and will ensure the power system equipment is not overloaded by DER generation.

• Provide these DER capabilities from the DERMS or AM/FM system, as well as any real-time DER status information from the DER SCADA to distribution management systems (DMS) to perform contingency analysis, volt-var optimization, and other distribution management functions.

• Coordinate the DER requirements with the distribution automation requirements via the utility DMS.

• Respond to efficiency and reliability requests from the utility DMS by issuing requests for modified DER outputs through the DER SCADA. Some of the types of management include requesting specific levels of energy output, requesting reactive energy output (vars), requesting low/high voltage ride-through to mitigate




System (DMS)

Outage Management

System (OMS)

System to Establish Demand

Response (DR) Pricing


Model (TBLM)


Monitoring

Utility WAN/LAN


System (GIS)

30


possible outages, requesting frequency support, and managing the formation of microgrids.

• Coordinate the determination of pricing information between the DMS and the demand response (DR) system.

• Respond to market pricing information from the DR system by providing this information to the Retail Energy Providers and to the FDEMS systems.

• Provide load, generation, and ancillary services forecasts based on DMS forecasts to the ISO/RTOs.

• Respond to emergency commands from the distribution management system and/or outage management system by broadcasting/multicasting commands to DER and FDEMS systems.

As a result, the utility systems may determine that certain DER systems should either be “commanded” or “requested” (depending upon tariffs and other contracts) to modify their output, such as limiting energy output, providing additional vars, counteracting frequency deviations, or (for EV chargers and storage devices) modifying the rate of charging.

2.5 Level 5: DER Integration with Transmission and Market Operations Architecture

At Level 5, Independent System Operators (ISO) or Regional Transmission Operators (RTOs) and market operations can affect what the DER systems are requested or commanded to do, based on tariffs and other agreements. Therefore, DER operations need to be integrated with the larger grid operations, including transmission and market operations. Distribution utilities must also interact (either directly or indirectly) with their ISO/RTO as a wholesale market participant, and must provide generation and load data to the ISO/RTO in order to meet the North American Electric Reliability Corporation (NERC) reliability requirements. The same types of information must be provided by REPs or other types of energy service providers.

31


These interactions are shown in Figure 16, Level 5: DER Integration with Transmission and Market Operations.

Figure 16: Level 5: DER Integration with Transmission and Market Operations






System (DMS)

Outage Management

System (OMS)




Model (TBLM)


Monitoring

Utility Grid

Circuit breaker

Meter and PCC





(FDEMS)


Utility WAN/LAN


System

EV DER ControllerPV

Controller

PV Equipment

Diesel Controller

ECP ECPECPECP


System (GIS)

Energy Management



DER Aggregator

Demand Response

(DR) System


System



Battery Equipment



Diesel Generator


(FDEMS)



32

Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models 3 Advanced DER Functions to Support Grid Operations Not only are there many variations on the hierarchical architectures, DER systems can be engineered to provide many different functions that can support grid operations. The following subsections provide an overview of these DER functions: their objectives and constituent energy products.

3.1 Objectives of DER Management Functions The objectives of DER management functions can be described as:

• Interconnection and registration functions. These functions are predominantly off-line or back office functions. However, eventually the communications capabilities must be securely established to register the DER system (unless the DER system is “autonomous-only”). – Actors : Distributed Generation & Storage Management (DERMS) DER Generation and Storage system

• Financially driven efficiency and demand response functions. These functions include establishing settings (watts output, volt/var modes, frequency modes) and schedules for efficient operations. For autonomous-only DER systems, these settings would be installed in the factory or during installation. For DER management and DER broadcast architectures, requests or commands would be issued to ensure optimal overall power system efficiency (or other goal such as improved reliability). Although these functions are only minimally used today in the United States, they are starting to be mandated in Europe and other countries worldwide. – Actors: Distributed Generation & Storage Management (Operations domain) Distribution SCADA System (Operations domain) DER Generation and Storage system (Customer domain, although

could belong to utility) Electric Vehicle (EVSE/PEV) (Customer domain) Customer Energy Management System (Customer domain) Aggregator / Retail Energy Provider (Service Providers domain)

• Power system reliability emergency functions. These functions are either pre-set into the DER systems (e.g., anti-islanding tripping off if external power is lost) or broadcast commands for var, frequency, or watt output control. These may also include deliberate islanding commands (e.g., to avoid a blackout) with many significant changes demanded of the DER systems in order to “balance” generation and load in microgrid. These functions are also becoming of increasing importance as renewable energy increases its percentage as a source of energy, and again are being mandated in many countries.

33


– Actors: Distributed Generation & Storage Management (Operations domain) Distribution SCADA System (Operations domain) DER Generation and Storage system (Customer domain, although

could belong to utility) Electric Vehicle (EVSE/PEV) (Customer domain) Customer Energy Management System (Customer domain) Aggregator / Retail Energy Provider (Service Providers domain)

• DER protective relaying time-sensitive functions. These functions provide for public safety and equipment protection by rapidly shutting down DER systems under certain conditions, such as grid outages or DER failures. Protective relaying for larger DER systems is already required by utilities. – Actors: DER Generation and Storage system (Customer domain, although

could belong to utility)

• Maintenance functions. These functions must be clearly separated from operational functions to ensure protection of the DER system and the power grid. – Actors: DER Generation and Storage system (Customer domain, although

could belong to utility) Facilities DER Energy Management System (Customer domain) Aggregator / Retail Energy Provider (Service Providers domain)

3.2 DER Functions for Supporting Grid Operations DER systems are capable of providing many functions that support power system operations. These DER functions may be managed at different levels of the DER hierarchy. The most basic approach is for DER systems at Level 1 to contain pre-established settings (values, trigger points, and curves) that allow these systems to operate autonomously, based on these settings and certain locally monitored conditions. The DER systems would not require communications to operate within those pre-established settings. Additional functionality would include the ability to update these settings and/or activate different functions, using communications either directly from Level 2 or indirectly from Level 3. For example, the utility’s DERMS or DMS (through a “DER SCADA”) could multicast a “limit output” command to customers on a particular feeder through their FDEMS (in Level 2), which in turn could manage the DER units in Level 1 to comply with that limit. Additional DER functions reflecting the operations of microgrids are provided in work from the DRGS Subgroup C, Microgrids and Hierarchical Distributed Control Subgroup.

34

Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models Schedules of functions and settings can also be used to pre-establish these to be activated at specific dates and times. At Level 4, distribution utilities would need to analyze their systems and determine what settings should be established for different locations and capabilities of DER systems. RTOs and ISOs could also request specific types of ancillary services from DER systems at Level 5.

3.3 Advanced DER Functions Advanced DER functions are actually executed by DER systems at DER Level 1, either as pre-established settings or upon a real-time command by a system at a higher level (DER Levels 2-5). The pre-established settings may be the default values established when the DER system was installed, or they may have been updated through communications from a higher level. At the higher DER Levels, analysis functions are used by higher-level systems to collect information from DER systems (either directly or in aggregate from lower-level systems) and to determine what settings and/or what commands should be issued to the DER systems. The list of advanced DER functions includes:

• Real and/or reactive power functions – Limit maximum real power output to a preset value – Limit maximum real power output upon a direct command – Set actual real power output – Schedule actual or maximum real power output – Modify real and/or reactive power output autonomously to smooth

voltage variations – Set or schedule the storage of energy for later delivery – Provide backup power after disconnecting from grid – Ramp real power up and down as necessary to avoid disruptive

transitions – Provide fixed power factor and/or specified amount of vars – Provide reactive power for voltage control based on locally

measured parameters, such as voltage, current, time, temperature, and combinations of these parameters

– Determine and respect DER capability curves in W-Var-Volt coordinates

• Frequency support – Smooth minor frequency deviations by changing real power output

in response to local frequency measurements – Support frequency regulation by responding to Automatic

Generation Control (AGC) commands from higher-level systems, such as Level 2 for microgrids or Level 5 for ISO/RTO management

• Response to emergencies

35


– Support anti-islanding through preset parameters and/or protective relaying

– Support direct command to disconnect or reconnect from a higher-level system

– Provide ride-through of low/high voltage excursions – Provide ride-through of low/high frequency excursions – Counteract voltage excursions beyond normal limits by providing

dynamic current support – Counteract frequency excursions by modifying real power – Reconnect using soft-start techniques after grid power is restored – Provide “spinning” or operational reserve as bid into market by

higher-level systems – Create microgrid, initiated by Level 2 or higher systems – Provide black start capabilities under the direction of higher-level

systems – Manage DER under conditions of distribution contingencies in

coordination with other EPS actions – Manage DER under conditions of bulk power system contingencies

in coordination with other EPS actions

• Integrated Volt/Var/Watt optimization for steady-state and variable conditions, performed by higher-level systems (4 and 5) that then request or command DER systems at levels 1 or 2 (via level 3) to set their parameters to the optimized values – Integrated Volt/Var/Watt optimization with taking into account

autonomous DER operations where these autonomous settings are not “easily” modified

– Integrated Volt/Var/Watt optimization with central control of DER operations where autonomous settings may be directly modified

• Economic objectives for generation functions, usually combined with load management functions – Net metering management at the PCC by combining load

management with controllable DER, electric storage (ES), and microgrids only

– Net metering management at the PCC by using Demand Response (DR) pricing signals for combining load management with controllable DER, ES, and microgrids

– Manage real power output of DER systems by responding to DR pricing signals

– Provide selected ancillary services by DER systems by responding to DR pricing signals

– Provide low cost energy as determined by higher-level systems – Provide low emissions energy as determined by higher-level

systems – Provide renewable energy as determined by higher-level systems

36


• Wide area situational awareness by higher-level systems – Provide emergency alarms and information from DER systems to

higher-level systems – Provide status and measurements from DER systems to higher-level

systems – Forecast of available energy and ancillary services by DER systems

and provided to higher-level systems – For transmission domain, provide aggregated DER information for

substations – Provide additional DER information needed for analysis covering

distribution, transmission, and ISO/RTO requirements

• Schedules – Start schedules for energy and ancillary services – Issue generation and storage schedules

• Communications and cybersecurity – Provide the capability to interface DER systems with communication

modules – Support TCP/IP Internet protocols – Provide transport layer security – Support the use of international DER data and information models – Support the mapping of data models to application protocols – Provide application layer and User cybersecurity

• Interconnection and maintenance – Initiate automated “discovery” of DER systems – Provide operational characteristics at initial interconnection and

upon changes – Test DER software patching and updates

• Maintenance and planning , including safety and cybersecurity requirements – Provide DER information for system planning purposes to higher-

level systems – Provide DER information for operational planning purposes to

higher-level systems – Provide communications information for maintenance, performance,

and cybersecurity purposes to higher-level systems These advanced DER functions are described in more detail in Appendices A and B.

37


4 Information and Communication Technology (ICT) Requirements

Information and communications are becoming increasingly important for monitoring and controlling the vast number of DER Systems. This monitoring and control will be managed primarily through the hierarchical infrastructures, and will involve many different information and communication technologies. The following sections outline some of the typical information and communication technologies (ICT) used for power system operations, and which are applicable to DER system ICT requirements even if they have not yet been deployed for DER systems.

4.1 Applicable Communication Standards

4.1.1 IEC TC 57 Standards Applied to Utility Domains The IEC Technical Committee (TC) 57, Power Systems Management and Associated Information Exchange, has developed many standards that are

designed for use in power system operations. Figure 17, IEC TC 57 Standards Applicable to Different Power System Domains, illustrates where these standards

are typically utilized.

Figure 17: IEC TC 57 Standards Applicable to Different Power System Domains5

5 Derived from IEC 62351-10

Back Office Market System

EMS Apps.

DMS Apps.

SCADA

Communication Bus

RTUs Substation Automation Systems

Protection, Control, Metering

Switchgear, Transformers, Instrumental Transformers

IEC 61970 IEC 61968

IEC 61970

IEC 60870-6 TASE.2/ICCP

IEC

6087

0-5-

102

6087

0-5-

101/

104

SS-C

CIE

C 61

850

IEC

6232

5

IEC

6196

8

SS-SSIEC 61850

DER Generator

IEC 61850-90-7, 8, 9, 10, 15

DER Storage

IEC

6185

0-7-

420

IEC

6185

0-7-

410

IEEE

181

5 (D

NP3)

IEC 62351 Cybersecurity

Control Center A

Distributed Energy Resources (DER)

Control Center B

Hydroelectric/ Gas Turbine Power Plants

Substations / Field Devices

GOOSE, SVIEC 61850

IEC 60870-5-103 IEC 61850

PMUs

IEC 61850-90-5

IEC 61850

Turbine and electric systems

Hydro systems

Electric Vehicle

38

Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models 4.1.2 Smart Grid Standards Used for DER Systems by Utilities Figure 18, Smart Grid Standards Used for DER Systems by Utilities, illustrates the broader range of ICT standards typically used by utilities. These standards are shown in relationship to the GridWise Architecture Council (GWAC)6 communications stack.

Figure 18: Smart Grid Standards Used for DER Systems by Utilities

4.1.3 Customer-based SG Standards Used for DER Systems Figure 19, Customer-based SG Standards Used for DER Systems, illustrates the range of ICT standards typically used for customer-based Smart Grid applications. These standards are shown in relationship to the GridWise Architecture Council (GWAC)7 communications stack.

6 http://www.gridwiseac.org/about/imm.aspx 7 http://www.gridwiseac.org/about/imm.aspx

39


Figure 19: Customer-based SG Standards Used for DER Systems

4.1.4 Standards Expected to be Used with DER Systems Some of the standards shown in the previous sections are expected to be used with DER systems. These are illustrated as an overlay on the five-level hierarchical DER model in Figure 20, Standards Expected to Be Used with DER Systems.

40


Figure 20: Standards Expected to Be Used with DER Systems

4.2 Analysis of Specific Protocols The following sections outline the structure and capabilities of the key power system protocols, including possible mappings and cybersecurity.

4.2.1 IEC 61850 for DER Systems IEC 61850, Communications Networks and Systems for Power Utility Automation, specifies:

• Abstract information models (semantic models) for substation automation (7-4), bulk generation plants (7-410), distributed energy resources (7-420 and 90-7), electric vehicles (90-8), distribution automation (90-6), and wind power (IEC 61400).

• Communication services (application layer messaging services) focused on interactions to and between field devices.






System (DMS)

Outage Management

System (OMS)




Model (TBLM)


Monitoring

Utility Grid

Circuit breaker

Meter and PCC





(FDEMS)


Utility WAN/LAN


System

EV DER ControllerPV

Controller

PV Equipment

Diesel Controller

ECP ECPECPECP


System (GIS)

Energy Management



DER Aggregator

Demand Response

(DR) System


System



IEC 61850 over SEP 2, BACnet,

or other facility protocol

Market information


CIM

IEC 61850 over

DNP3 or XMPP

IEC 61850 over ??

IEC 61850 over

DNP3 or XMPP

Battery Equipment



Diesel Generator


(FDEMS)



Market inform

ation in

OpenADR and/or IEC 62746

CIM or ICCP

41


IEC 6150 abstract information models can be “mapped” to:

• MMS (Manufacturing Messaging Specification). It is the primary and most implemented mapping.

• DNP3 (Distributed Network Protocol 3)(DER).

• SEP 2.0 (Smart Energy Profile Application Protocol) (DER and EV).

• Web services (Extensible Messaging and Presence Protocol (XMPP), OPC/UA, or other).

The semantic models do not need to address security because they are abstract. The communication services identify the security requirements, and then state that other standards will provide the security technologies to meet those requirements. Cybersecurity for IEC 61850 is provided primarily through IEC 62351, Power systems management and associated information exchange - Data and communications security. Figure 21, Security Profile for DER using IEC 61850 Standards, illustrates the security profile for DER using IEC 61850 communications.

Figure 21: Security Profile for DER using IEC 61850 Standards

42

Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models 4.2.2 IEC 62351 for Data and Communication Security for Power Systems IEC 623518 provides cybersecurity for the communication protocols defined by the IEC TC 57 series of protocols, including:

• IEC 60870-5 for SCADA communications, including DNP3

• IEC 60870-6 for ICCP (Inter-Control Center Communications Protocol)

• IEC 61850 for field communications

• IEC 61968 and IEC 61970 for the CIM (Common Information Model) IEC 62351 series (Parts 3-11) covers:

• Security for the transport layers (Transport Layer Security – TLS)

• Security for MMS (for 61850 mapping to MMS)

• Security for SCADA communications (for 870-5 and DNP3)

• Security for GOOSE and SV (for 61850 high-speed profile)

• Security for comm. networks through network management (e.g., SNMP)

• Security through Role-Based Access Control (RBAC)

• Security of cryptography through key management

• Security architecture of IEC TC57 information and communications

• Security for XML-based communications (e.g., CIM messages)

4.2.3 IEEE 1815 (DNP3) IEEE 1815, Standard for Electric Power Systems Communications-Distributed Network Protocol (DNP3), is a SCADA protocol used for interactions between a SCADA system and remote devices. DNP3 has no associated abstract information model. Just a few types of data are identified:

• Status

• Control

• Analog measurements

• Analog settings Because most end devices are relatively compute-constrained and communications are bandwidth-constrained, DNP3 requires only authentication,

8 More details can be found in the WG15 White Paper at http://iectc57.ucaiug.org/wg15public/default.aspx

43


not confidentiality, and uses symmetric keys (not asymmetric public/private key pairs):

• Authentication is provided by Message Authentication Code (MAC) hashing of messages.

• Cryptographic symmetric keys are used by the MAC to authenticate, challenge, and validate clients and servers.

• TLS and/or VPNs can be used at the transport layer, particularly to distribute the symmetric keys initially and upon update.

• The method for managing the symmetric keys could be provided by IEC 62351-9, but this has not yet been decided.

4.2.4 OpenADR The OpenADR 2.0 profile specification is a data model to facilitate the exchange of demand response (DR) information between electricity service providers, aggregators, and end users. As stated in the OpenADR 2.0 Profile B document, “OpenADR 1.0 was developed to support Auto-DR programs and California’s energy policy objectives to move toward dynamic pricing to improve the economics and reliability of the electric grid. The recent developments have expanded the use of OpenADR to meet diverse market needs such as ancillary services (Fast DR), dynamic prices, intermittent renewable resources, supplement grid-scale storage, electric vehicles, and load as generation. For example, with real-time price information, an automated client within the customer facility can be designed to continuously monitor these prices and translate this information into continuous automated control and response strategies. This rationale is a fundamental element of the United States (U.S.) Smart Grid interoperability standards, which are developed to improve dynamic optimization of electric supply and demand.”

4.2.5 OPC/UA Object Linking and Embedding for Process Control (OPC) Unified Architecture (UA) OPC/UA is a general specification for exchanging XML-based information and can be used for command and control in industrial processes. It covers the transport layers and the general information model for exchanging data at the application layers, but does not specify any domain-specific information model. OPC/UA can be used to exchange CIM data. OPC/UA security covers the requirements for establishing secure channels, managing keys, providing audit logs, and most other general security requirements. Additional security is needed beyond the scope of OPC/UA:

• Identity establishment

• Role-Based Access Control (RBAC)

• Key management

44


• Validation of information models and the data values being exchanged

4.2.6 Smart Energy Profile (SEP 2.0) The Smart Energy Profile Application Protocol (SEP 2.0) is designed to be a protocol for exchanging IEC 61968 CIM data, mapping directly where possible, and using subsets and extensions where needed. SEP 2.0 follows a RESTful architecture. This architecture lends itself to loosely coupled interactions. SEP 2.0’s initial scope is customer premises, but it could be used in other environments. The SEP 2.0 specification provides limited security, based on the expectation that it would be used primarily by home appliances, so additional security technologies are needed if it is used for DER systems.

4.2.7 ANSI C12.22 ANSI C12.22, Protocol Specification for Interfacing to Data Communication Networks, is used for communications with electric meters. The purpose of the ANSI C12.22 standard is to define the network framework and the means to transport the ANSI C12.19, Utility Industry End Device Data Tables, via any reliable network, such as a Local Area Network (LAN) or Wide Area Network (WAN) for use by metering or enterprise systems in a multi-vendor sourced environment. ANSI C12.22 is reviewing their cybersecurity requirements and has started work on updating the security requirements.

4.3 Resilience and Cybersecurity Requirements Resilience and cybersecurity are covered in more detail in a separate document,9 but this section introduces the concepts of resilience, cyber-physical systems, and cybersecurity. In the energy cybersecurity sector, two key words are becoming the focus of international and national policies: resilience and cyber-physical. Resilience implies that the power system critical infrastructure is designed and operated not only to prevent malicious attacks and inadvertent failures, but also to cope with and recover from such attacks and failures in a timely manner. Cyber-physical implies that the power system consists of both cyber and physical assets that are tightly intertwined and can effectively be used in combination to improve the resilience of the power system infrastructure. Resilience responds to the concern: "I don't care what the cause of a problem is - cyber, physical, malicious, or inadvertent - but I want that critical infrastructure, the Smart Electric Grid, to be resilient - to be protected against problems when possible, and to cope and recover from the inevitable crises with minimal disruptions." CERT-RMM defines operational resilience as “the emergent property of an organization that can continue to carry out its mission in the presence of operational stress and disruption that does not exceed its limit,”

9 “Resiliency and Security for DER Cyber-Physical Systems”, The latest version can be found at http://members.sgip.org/apps/org/workgroup/sgip-drgs-b/documents.php?folder_id=122

45


including the note that the system must be able to recover to its normal operating state once the disruption has ended.10 All too often, cybersecurity experts concentrate only on traditional “IT cybersecurity” for protecting the cyber assets, without focusing on the overall resilience of the physical assets. At the same time, power system experts concentrate only on traditional “power system security” based on the engineering design and operational strategies that keep the physical and electrical assets safe and functioning correctly, without focusing on the security of the cyber assets. But the two must be combined: resilience of the overall cyber-physical system must include tightly entwined cybersecurity technologies and physical asset engineering and operations. As an example, distributed energy resources (DER) systems are cyber-physical systems that are increasingly being interconnected to the distribution power system to provide energy and ancillary services. However, distribution power systems were not originally designed to handle these dispersed sources of generation, while DER systems are generally not under direct utility management or under the security policies and procedures of the utilities. Many DER systems provide energy from renewable sources, which are not reliably available at all times. Therefore, the resilience of power systems is increasingly at risk as more of these DER systems are interconnected. On the other hand, the sophisticated cyber-physical capabilities of smart DER systems could actually improve power system resilience if these smart DER capabilities were properly secure and coordinated with power system management. Moreover, networked DER systems (microgrids) and the bulk power system can serve as mutual backups during excessive peak loads or during disaster conditions. So, as illustrated in Figure 22, Components of Resilience of the Cyber-Physical Smart Grid, if both the cyber and the physical components of these DER systems were well designed and implemented with embedded cybersecurity, and were interconnected and operated using good engineering strategies, they would significantly improve the resilience of the power system.

10 CERT® Resilience Management Model: A Maturity Model for Managing Operational Resilience and the CERT Resilience Management Model pages on the CERT website [Caralli 2011, CERT 2012].

46


Figure 22: Components of Resilience of the Cyber-Physical Smart Grid

It is not just the utilities who must take responsibility for achieving this resilience goal. Many stakeholders are involved in the design, implementation, and operation of DER systems, including manufacturers, integrator/ installers, users, information and communication technology (ICT) providers, security managers, testing and maintenance personnel, and, ultimately, utility regulators. However, given this new cyber-physical environment, often these stakeholders do not fully understand or appreciate the types of cybersecurity and engineering strategies that could or should be used.

5 Categorization of DER systems and Gap Analysis of DER Use Cases

5.1 Approach to Identifying and Categorizing DER Systems In this document, the terms “function,” “use case,” and “category” are utilized in the following ways:

• Functions are analysis activities performed by computer systems and devices that use information from the power system and other sources to determine control actions for power system equipment, including DER systems. These functions may be simple, such as “measure voltage and respond by changing vars” or may be very complex, such as “optimize generation and storage across the grid for greatest efficiency.” Advanced DER functions are those that “smart” DER systems can perform.

• Use cases are used to describe the methods and interactions between actors for achieving different purposes, and can utilize many different

Resilience of the Cyber-Physical Smart Grid

“IT” Cyber Security Requirements for the

Smart Grid

Engineering Design and Operational Strategies for the

Smart Grid

47


functions to support those purposes. Use cases may also be hierarchical by including lower-level use cases to achieve sub-purposes. Often the same functions can be used by different use cases to achieve different purposes.

• Categories are ways for grouping DER systems for convenience and for understanding the range of different use cases and the types of functions each use case might utilize for its purposes.

DER systems may be categorized by DER Level and by the purposes they support. These categorizations may be envisioned as shown in Figure 23, Structure of Use Cases within the DER Hierarchy, which indicates the 5 DER levels vertically and the purposes of registration, analysis, operations, and maintenance in the horizontal plane.

Figure 23: Structure of Use Cases within the DER Hierarchy

As can be seen from the diagram, the “operations” activities category has the most widespread and complex use cases, covering many different types of DER functions for managing the power grid reliably, safely, and efficiently. There is not a one-to-one correspondence between higher-level functions and lower-level functions, and a convenient method for categorizing these functions is to define primary (local) control functions as Level 1 and Level 2 functions, and to define secondary (central) control functions as Level 4, although Level 5 requirements may influence Level 4 requirements. The secondary control functions take a

ISO/RTO: Assess economic needs of

transmission

ISO/RTO: Assess reliability needs of

transmission

DSO: Determine economic settings

for DERs

DSO: Determine reliability settings

for DERs

DSO: Determine market prices for DER capabilities

DSO: Study and plan for DER

interconnections

FDEMS: Update autonomous

settings

FDEMS: Monitor and control

DERs

FDEMS: Manage transition & operation

of microgrid

FDEMS: Respond to

pricing signals

Hierarchical and Categorized Matrix of DER Use Cases

DSO or REP: Manage virtual

power plant

DSO or REP: Manage FDEMS in industrial sites

DSO or REP: Manage DER power plant

DSO or REP: Manage FDEMS

in residences

Level 1: DER Systems

Level 5: ISO/RTO/TSO &

Markets

Level 4: DSO Analysis &

Studies

Level 3: ICT Information &

Communications

Level 2: Facility Energy

Management

DSO: Manage DER in

substation

DSO or REP: Manage DER

microgrids

Market initiates Demand Response

request

DSO: Register nameplate info

for DERs

DERs register in market for participation in

Demand Response

FDEMS: Register DER

capabilities

Interconnection OperationsAnalysis & StudiesUpdate &

Maintenance

FDEMS: Analyze DER capabilities

DER: Real-power functions

DER: Reactive power

functions

DER: Emergency functions

DER: Frequency functions

DER: update/ maintenance

functions

DER: Development & Interconnection

FDEMS: Update &

maintenance

ISO/RTO/TSO: Command DER

services thru DSO

DSO: Establish communications

DSO: Wide area situational awareness

Categories of Functions by their Purposes

Hie

rarc

hica

l Lev

els

of F

unct

ions

DER: Testing and integration

REP: Manage DER directly at customer site

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Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models more global view of requirements and use the primary control functions to carry out the required actions. The information exchange requirements (Level 3) for interacting between the primary and the secondary control functions can also be described in use cases. Most of the primary control functions are defined in [1] and are listed in Appendix A. A tentative list of secondary control functions is presented in Appendix B; however, some of them are represented from the Level 1 perspective in Appendix A. The possible combinations of use cases for power system operations with DER functions are incalculable. Multiple DER functions may be combined in different ways to create use cases with similar purposes. These use cases, in turn, may be combined with other use cases that cover different types or capabilities of DER systems, to achieve another purpose. Each combination of use cases may include a different list of actors and object models. Each combination of DER functions participates in a number of distribution and transmission operation use cases. The information exchange between actors of each combination of DER functions and other actors involved in the functions may be different for each function and for each combination. Even if these use cases are categorized to minimize slight variations, the number of use cases is still huge because actions involving different interfaces between actors and/or different messages delivered through the interfaces constitute different use cases. The number of theoretically possible use cases is as follows:

N_use_cases = Nc1 × N c2 ×….× N cn × N_functions, where

Nc1 , N c2 , N cn - number of categories in groups 1, 2,…n This is a very large number, and development of such a number of use cases is impractical and probably not useful. However, all actors, object/data models, interfaces, and messages involved in the most important use cases should be defined and covered in international interoperability standards. The primary need is to determine whether and where gaps in these international standards might exist. Because attempting to develop an exhaustive list of all possible use cases is infeasible, the next approach is to categorize the different types, configurations, purposes, and management structures of DER systems so that sample use cases can be identified by selecting representative use cases from these categories.

5.2 Possible Categorizations of DER Systems The first step to identifying gaps in international standards is to develop different types of categories for DER systems to minimize the number of variations. Although possibly not 100% inclusive of all possible scenarios, most scenarios involving DER systems may be categorized according to the following criteria:

• Configuration of grid connection

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• Logical and/or islanded microgrids • Management authority • Communications capabilities • DER type and functional capabilities

5.2.1 Categorization as Configuration of Grid Connection DER systems may be located within many types of facilities, including:

• Within a residence • Within a building (office, apartment, commercial, industrial) • Within a community • Within a real power plant like a wind farm • Within a virtual power plant • Within a substation • Within a campus environment • Within a military environment • Within a distribution feeder as a stand-alone DER or group of DERs as a

distribution-connected power plant • Within an islanded microgrid

5.2.2 Categorization as Logical and/or Islanded Microgrids Microgrids are defined as portions of the grid that may be connected to the area EPS some or even most of the time, but are capable of being islanded if necessary or if economically beneficial;

• As permanent island • As backup for any configuration • Autonomous decentralized control • Pre-planned microgrid with combined management and autonomous • Emergency microgrid with after-the-fact management • AC vs. DC microgrids, including combinations of AC and DC • Transitions between grid-connected and islanded, including UPS systems

for backup • Multiple logical and/or islanded microgrid monitoring and analysis (e.g.,

networked microgrids or meshed microgrids or active distribution networks)

5.2.3 Categorization by Management Authority DER systems may be owned and/or managed by different authorities:

• Private customer • Retail energy providers (REP) • Utility with direct control • Cooperative control between customer and utility • Virtual power plant (VPP) • Demand response and other financial signals

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Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models 5.2.4 Categorization by Communications Capabilities DER systems may be categorized by their communications capabilities, ranging from no communications (autonomous operations) to near-real-time monitoring and control:

• Autonomous no monitoring, no control • Autonomous with monitoring, no control • Autonomous no monitoring, with decentralized control • Autonomous with monitoring and decentralized control • Autonomous no monitoring, with broadcast instructions and decentralized

control • With near-real-time monitoring, with direct communications and

autonomous control • With near-real-time monitoring, with direct communications and central

control (DMS)

5.2.5 Categorization by DER Type and Functional Capabilities DER systems may be categorized by their type:

• Composite DER • Synchronous generation • Micro-turbines with advanced inverter capabilities • Solar (PV and thermal) with advanced inverter capabilities • Fuel cell with advanced inverter capabilities • EV with V2G capabilities • Solar (PV and thermal) without advanced inverter capabilities • Fuel cell without advanced inverter capabilities • Storage without advanced inverter capabilities • Storage with advanced inverter capabilities

5.3 List of DER Use Cases A list of DER use cases organized by Level and by other subcategories is in a separate document called “IEC TC8 WG6 DER Use Cases - DRGS version.”11 That document does not explicitly identify the categories of the DER systems, but could be used to do so.

11 See http://members.sgip.org/apps/org/workgroup/sgip-drgs-b/download.php/974/IEC%20TC8%20WG6%20DER%20Use%20Cases%20-%20DRGS%20version.docx

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http://members.sgip.org/apps/org/workgroup/sgip-drgs-b/download.php/974/IEC%20TC8%20WG6%20DER%20Use%20Cases%20-%20DRGS%20version.docx




5.4 Gap Analysis Process for Expanding DER Use Cases

5.4.1 Selection of Use Cases The following method is proposed for determining if gaps in standards exist:

1. Select a subset of existing use cases that cover the key DER management requirements. Expand these use cases to identify the actors and the information exchange requirements. As an example, the following use cases might be selected:

a. For Levels 1 and 2: i. Limit maximum real power output at the PCC to a preset

value ii. Provide dynamic reactive power injection through

autonomous responses to local voltage measurements iii. Support direct command to disconnect or reconnect iv. Provide ride-through of low/high voltage excursions beyond

normal limits v. Provide ride-through of low/high frequency excursions

beyond normal limits b. For Level 3:

i. Monitor the status of DER systems, either directly or through FDEMS

ii. Issue setting updates to selected DER systems, either directly or through FDEMS

iii. Issue control commands to groups of DER systems, either directly or through FDEMS

iv. Issue requests or DR pricing signals for energy and ancillary services to utility-connected microgrids

c. For Levels 4 and 5: i. Analyze near-term grid conditions using Advanced

Distribution Automation (ADA) functions (see Distribution Grid Management Initiative [5])

ii. Provide situational awareness (see Distribution Grid Management Initiative [5])

iii. Use the Transmission Bus Load Model to exchange DER-related information between distribution utilities and RTOs/ISOs [4]

iv. Analyze Multiple DER within both radial and networked distribution circuits (see Distribution Grid Management Initiative [5])

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2. Identify existing use cases and/or develop a number of use cases for Levels 1-2 and one high-level most-common use case for Levels 4-5 with references to the Level 1-2 use cases and related Level 3 use cases. These use cases can be based on current expert knowledge and intuitive determining of actors, interfaces, object models, actuators, and messages without detailed use cases.

5.4.2 Gap Analysis Process Most of the existing use cases involving DER were developed without addressing the specifics of all relevant DER categories. The suggested process for expanding existing use cases to address these specifics is described in the following steps:

1. For each of the selected use cases, check which DER categories are involved, but not addressed in the use case

2. Take the step-by-step actions table of the existing use case and crosscheck whether the steps cover the selected categories for this use case with DER integration. If some actions are not covered, it indicates the gaps in the use case, which may also be gaps in the standards.

a. Include general comment for the step, taking into account the overall knowledge about the categories

b. Include specific comments for individual categories c. Some steps are not relevant for some categories d. Some steps for some categories do not need standardization

3. Address the gaps, based on the comments. These gaps may be missing actors, object/data models, and information exchanges.

4. Take the table of actors from the existing use cases and crosscheck the coverage of all relevant DER categories by the existing list of actors and suggest missing actors and/or additional functionalities of actors.

5. Take the table of interfaces from the existing use case and crosscheck the coverage for all relevant DER categories and suggest additional messages for the existing interfaces and additional interfaces, if needed.

6. Supplement the step-by-step table to cover all DER categories (additional actors and/or additional functionalities of the existing actors will require additional steps and interfaces).

7. Compose full lists of actors, object/data models, and interfaces with messages.

8. Categorize the object/data models, interfaces, and messages by standards.

9. Crosscheck the coverage of the object/data models, interfaces, and messages by the standards.

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10. Define the gaps in the standards.

Illustrations of the crosschecking described in the above list are presented in Appendix C. The illustrations are based on the Distribution Grid Management Initiative use cases [5]. These use cases include:

• Distribution Situational Awareness (based on Distribution Operation Modeling and Analysis application - DOMA)

• Integrated Volt/Var/Watt Optimization (IVVWO) • Fault Location, Isolation, and Service Restoration (FLISR)

o Distributed Intelligence o Centralized Intelligence

• Multi-level Feeder Reconfiguration (MFR) Appendix D illustrates gap analysis of the standards for Levels 1, 2, and 3 of the DER Volt-Var Use Case (Interface table).

6 Conclusions and Next Steps This document covers the following topics:

• Describes the five-level hierarchical architecture of DER systems, including variations of configurations and management infrastructures.

• Presents advanced functions involving DER systems, associating them with different hierarchical levels.

• Discusses the need for expanding DER-related use cases to determine whether gaps exist in international standards, and states the impracticality of undertaking an exhaustive update of these use cases for all configurations, purposes, types, functions, and management techniques of DER systems.

• Develops a proposed process for managing this “big data” problem by categorizing DER systems and using those categorizations to determine whether DER use cases have covered all appropriate categories, as a first step to determine if gaps still exist in international standards.

• Provides some high-level examples for using these categories to analyze DER use cases in Appendices C and D. However, the actual work of identifying gaps in international standards has not yet been undertaken.

The next phase of this work should complete the gap analysis for some example DER use cases as a proof of concept. The following results of the work performed, based on the methodology suggested in this paper, would then be submitted to the appropriate international standards development bodies for their use in filling the gaps in their standards:

• The lists of new actors, object/data models, and interfaces with messages.

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• The categorization of the new object/data models, interfaces, and messages by the interoperability standards.

• The gaps in the standards based on crosschecking the coverage of the new object/data models, interfaces, and messages by the standards.

7 References 1. Smart Grid Interoperability Panel (SGIP 1) web site: “Advanced Functions for

DER Systems Modeled in IEC 61850-90-7” at http://collaborate.nist.gov/twiki-sggrid/pub/SmartGrid/PAP07Storage/Advanced_Functions_for_DER_Inverters_Modeled_in_IEC_61850-90-7.pdf

2. Concept and Controllability of Virtual Power Plants, by Eko Sadhi Satiawan, Available: http://www.uni-kassel.de/upress/online/frei/978-3-89958-309-0.volltext.frei.pdf

3. Nokhum Markushevich, Update on the Use Case for the Transmission Bus Load Model, Available: http://collaborate.nist.gov/twiki-sggrid/pub/SmartGrid/TnD/Update_on_TBLM_SGIP_2012_Winter__Meeting.pdf

4. Development of Transmission Bus Load Model (TBLM) Use cases for DMS support of information exchange between DMS and EMS, Available: http://collaborate.nist.gov/twiki-sggrid/pub/SmartGrid/TnD/TBLMUseCase_V13-09-12-12.pdf

Distribution Grid Management (Advanced Distribution Automation) Functions. Use Case Description, Available: http://collaborate.nist.gov/twiki-sggrid/bin/view/SmartGrid/PAP08DistrObjMultispeak

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http://collaborate.nist.gov/twiki-sggrid/pub/SmartGrid/PAP07Storage/Advanced_Functions_for_DER_Inverters_Modeled_in_IEC_61850-90-7.pdf



http://www.uni-kassel.de/upress/online/frei/978-3-89958-309-0.volltext.frei.pdf

http://www.uni-kassel.de/upress/online/frei/978-3-89958-309-0.volltext.frei.pdf

http://collaborate.nist.gov/twiki-sggrid/pub/SmartGrid/TnD/Update_on_TBLM_SGIP_2012_Winter__Meeting.pdf



http://collaborate.nist.gov/twiki-sggrid/pub/SmartGrid/TnD/TBLMUseCase_V13-09-12-12.pdf

http://collaborate.nist.gov/twiki-sggrid/pub/SmartGrid/TnD/TBLMUseCase_V13-09-12-12.pdf


Appendix A. Use Cases of Level 1 DER Operational Functions The Use Cases of DER operational functions in Table 1 use the brief format for Use Cases as identified in the draft Committee Draft of IEC 62559-2, Use case methodology - Part 2: Definition of use case template, actor list and requirement list from IEC Technical Committee 8, Systems aspects for electrical energy supply, Working Group 5, Methodology and Tools. Table 1: Use Cases of DER Operational Functions Use Case Name Short Description and Interactions Actors Information

Requirements A.1 Real Power Use Cases

Generate energy at any time within contractual limits

The DER system generates energy at any time within its contractual limits. If required by those contract parameters, decrease or increase energy output at ECP or PCC to remain within contractual limits.

• Contractual limits established in DER system either manually as pre-set or by DER management system

• DER system monitors the energy output at the ECP or at the PCC (larger DER systems)

• DER system autonomously maintains the energy output within the contractual limits if technically possible, by decreasing or increasing the energy output at the ECP or PCC through available combinations of generation, storage, and controllable loads

DER system (including generation, storage, and/or controllable load) DER management system

Autonomous Local monitoring: Monitor output at PCC if large DER Already in IEC 61850-7-420

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Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models Use Case Name Short Description and Interactions Actors Information

Requirements Support direct command to limit maximum energy output

The DER system is commanded to limit its maximum energy output at the ECP or the PCC.

• DER management system issues a direct command to limit the maximum energy output at the ECP or the PCC

• DER system monitors the energy output at the ECP or at the PCC (larger DER systems)

• DER system autonomously decreases the energy output if necessary to limit the energy output at the ECP or PCC through available combinations of generation, storage, and controllable loads

DER system (including generation, storage, and/or controllable load) DER management system (at DSO, REP, or FDEMS)

Remote direct command: Limit generation command from DSO, REP, or FDEMS Already in IEC 61850-7-420

Generate specified energy output at specific times to offset peak load

The DER system maintains a specific energy output at the ECP or PCC if technically possible.

• DER system contains pre-established and/or updatable Time-of-Use (TOU) schedules for on-peak and off-peak times

• At scheduled on-peak time, the DER system generates the required energy output at the ECP or PCC through available combinations of generation, storage, and controllable loads


Autonomous Remote: Update TOU by DSO, REP, or Customer DEMS (FDEMS) Already in IEC 61850-7-420

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Use Case Name Short Description and Interactions Actors Information Requirements

Modify energy output in response to local voltage variations in order to damp voltage deviations

The DER system dynamically modifies the energy output at the ECP or PCC in response to variations in the local voltage.

• DER system monitors the local voltage

• DER system modifies the energy output in order to damp voltage deviations

DER system (including generation, storage, and/or controllable load)

Autonomous Local: Monitor voltage Already in IEC 61850-7-420

Store energy for later delivery either by TOU schedule or by direct command

The DER system with storage capability, such as a PV system with battery storage, charges its storage for later delivery.

• DER system contains pre-established and/or updatable Time-of-Use (TOU) schedules for storage charging

• DER system contains state-of-charge (SOC) level requirements for each time period

• Alternatively, the DER management system issues a command for the DER system to reach a specified SOC level

• DER system charges its storage at a specified rate until the SOC reaches the specified level

• DER system charges in order to reach the specified SOC within the specified time

• DER management system updates the storage TOU schedule and SOC level requirement as needed


Autonomous Remote: Update storage settings and/or schedule by DSO, REP, or FDEMS Already in IEC 61850-7-420, but storage needs additional modelling

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Requirements Offset local loads through DER generation

The DER system monitors local loads (or imported energy at the ECP or PCC) and continuously offsets a percentage of that load.

• DER management system sets the percentage of load at the ECP or PCC that the DER system should offset

• DER system monitors the load at the ECP or PCC

• DER system increases or decreases it energy output to maintain the required load offset percentage


Autonomous Local: Monitor load at PCC Remote: Receive the percentage of load to offset or schedule for offset from DSO, REP, or FDEMS Already in IEC 61850-7-420

Provide backup power including balancing the generation with the load

If the area EPS power is lost, the DER system balances its energy output with the load at the ECP or PCC and maintains nominal frequency, if it is capable of operating when an external source of frequency is not available. This may be considered a type of microgrid.

• DER management system or pre-set manufacturer designs establish the backup settings for operating when the grid power is lost

• Upon loss of the area EPS power (and electrical separation from the area EPS), the DER system balances its generation to the local load within the DER system’s range

• Controllable load may also be decreased to help ensure the DER system can continue to balance generation and load


Autonomous Local: Monitor connected load Already in IEC 61850-7-420

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A.2 Reactive Power Use Cases

Provide reactive power by a fixed power factor

The DER system maintains a fixed power factor setting. • DER system contains pre-established power factor

setting, and/or

• DER management system updates the power factor setting

• DER system maintains the power factor at the required setting


Autonomous If pre-established settings are used, no communications needed Remote: Set power factor command from DSO, REP, or FDEMS Already in IEC 61850-7-420

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Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models Volt-var management by providing dynamic reactive power injection through autonomous responses to local voltage measurements

The DER system provides volt-var management through “curves” that define the reactive power for different voltage values above and below the desired voltage level. The purpose is to use vars to counteract deviations in voltage, with the goal of keeping voltage close to the desired voltage level.

• During interconnection analysis, DSO determines that DER system must include volt-var function to be optionally activated

• DSO and DER owner determine appropriate default volt-var mode settings, plus some additional available volt-var mode settings for different situations

• DER operator installs default and additional setting groups for volt-var modes

• DSO requests the DER operator to activate the default volt-var mode in all DER systems that are capable

• DER operator commands the FDEMS to activate volt-var modes in all capable DER systems

• FDEMS determines which DER systems are volt-var capable, and activates the volt-var mode in those DER systems (allocates the volt-var function)

• Each DER system sends an event notification to the FDEMS when it modifies its vars in response to voltage changes


Autonomous Local: Monitor voltage Remote: Update volt-var settings from DSO, REP, or FDEMS Already in IEC 61850-7-420

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• FDEMS aggregates the var amounts from each of the DER systems and provides this aggregated var amount to the DSO

Like temperature-activated capacitor banks, provide reactive power through autonomous responses to temperature

The DER system implements temperature-var settings that define the reactive power different ambient temperatures, similar to feeder capacitors.

• DER management system provides one or more temperature-var curves, and/or

• DER system contains pre-established temperature-var curves

• DER management system activates one temperature-var curve

• DER system monitors the local temperature and/or

• DER management system provides ambient temperature

• DER system modifies its var output to match the temperature-var curve


Autonomous Local: Monitor ambient temperature Remote: Update temperature-var settings from DSO, REP, or FDEMS Already in IEC 61850-7-420

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Requirements A.3 Frequency Support Use Cases

Support frequency regulation through autonomous modifications of real power output to counter frequency deviations

During normal operations, the DER system implements frequency-watt settings that define the percentage of watt output to modify for different frequency deviations on a second or even sub-second basis. In emergency situations, the DER system may use complex algorithms to reduce real power to counteract frequency excursions above upper normal limits (and vice versa if additional generation or storage is available). Hysteresis can be used as the frequency returns within the normal range to avoid sudden changes by multiple DER systems.

• DER management system provides one or more frequency-watt curves, and/or

• DER system contains pre-established frequency-watt curves

• DER management system activates one frequency-watt curve

• DER system monitors the frequency

• DER system modifies its var output to match the frequency-watt curve


Autonomous Local: Monitor frequency Remote: Update frequency-watt settings from DSO, REP, or FDEMS Already in IEC 61850-7-420

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Support frequency regulation by direct automatic generation control (AGC) commands

The DER system implements modification of real power output based on AGC signals on a multi-second basis.

• DER management system issues a command for a specific real power output

• DER system modifies its real power output to match the commanded value


Remote: Receive AGC commands to modify output Already in IEC 61850-7-420

A.4 Response to Emergencies Use Cases

Support anti-islanding to trip off under extended anomalous conditions

The DER system ceases to energize the EPS and/or disconnects from the EPS if voltage or frequency limits are exceeded over specified time periods.

• DER system determines if a potential unintentional island condition exists

• DER system ceases to energize the EPS if it determines that an unintentional island condition exists


Autonomous Local: Monitor voltage Local: Monitor frequency IEC 61850 would be used only if updates to the anti-islanded parameters are needed. This is stated but not actually modelled.

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Requirements Support direct command to disconnect or reconnect

The DER system performs a disconnect or reconnect at the PCC. Ramp rates and/or time windows are established for different DER systems to ramp up or down, or to respond randomly within that window to the trip and reconnect commands.

• DER management system issues a command to disconnect or to reconnect

• DER system disconnects or reconnects, using ramping and/or random time within a time window


Remote: Reconnect or trip command from DSO, REP, or FDEMS Already in IEC 61850-7-420 with possible addition of a reconnection ramp rate

Ride-through low/high voltage anomalies

The DER system remains connected during voltage anomalies based on parameters related to a window defined by voltage levels over time, disconnecting only when the ride-through window has expired.

• DER system has pre-established voltage-time limits and/or

• DER management system updates the voltage-time limits

• DER system monitors local voltage

• If the voltage exceeds the voltage-time limits, the DER system ceases to energize the EPS


Autonomous Local: Monitor voltage IEC 61850 would be used only if updates to the voltage-time limits are needed. This is stated but not actually modelled.

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Ride-through low/high frequency anomalies

The DER system remains connected during frequency anomalies based on parameters related to a window defined by frequency over time, disconnecting only when the ride-through window has expired.

• DER system has pre-established frequency-time limits and/or

• DER management system updates the frequency-time limits

• DER system monitors frequency

• If the frequency exceeds the frequency-time limits, the DER system ceases to energize the EPS


Autonomous Local: Monitor frequency IEC 61850 would be used only if updates to the frequency-time limits are needed. This is stated but not actually modelled.

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Requirements Dynamic current support to counteract voltage anomalies while only disconnecting if necessary

The DER system counteracts voltage anomalies (spikes or sags) through “dynamic current support” during the “ride-through” time duration, and disconnects if outside the ride-through window.

• DER management system provides dynamic current support values to DER system

• DER system monitors local voltage

• DER system activates dynamic current support if it determines it is within a voltage ride-through situation

• DER system either recovers from the voltage ride-through situation and deactivates the dynamic current support function, or it disconnects from the EPS if the voltage-time limits are exceeded


Autonomous Local: Monitor voltage anomalies Remote: Update dynamic ride-through settings from DSO or FDEMS Already in IEC 61850-7-420

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Provide “spinning” or operational reserve so that real power is available at short notice (seconds or minutes)

The DER system provides contracted real power upon command. The assumption is that generation can be provided through increasing generation or by discharging storage devices. The market process for establishing this contract is outside the scope of this use case.

• DER management system (at DSO, REP, of FDEMS) issues command to increase real power output to one or more DER management systems or directly to DER systems

• If necessary, the DER management system allocates the required generation increase to different DER systems, including storage

• DER system increases real power output


Remote: Increase output command for contracted amount from DSO, REP, or FDEMS Already in IEC 61850-7-420 although storage discharge command may need additional models

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Requirements Create microgrids to minimize the extent and length of power outages or other power quality issues

After grid power at the PCC is lost or upon command, the microgrid DER management system disconnects from the area EPS, notifies all DER systems that they should enter microgrid mode. The DER systems switch to microgrid mode and enter into “leading” or “following” mode depending upon preset parameters.

• Microgrid DER management system identifies a loss of area EPS power and/or

• Microgrid DER management system receives command to disconnect from the area EPS

• Microgrid DER management system disconnects from the area EPS

• Microgrid DER management system commands all DER systems to enter into microgrid mode

• DER systems enter into microgrid mode, which could entail changing what settings, limits, and functions to activate

• DER systems start leading or following local EPS voltage and frequency values

DER system (including generation, storage, and/or controllable load) DER management system (at DSO, REP, or FDEMS) Microgrid DER management system

Autonomous Local: Monitor voltage at PCC Remote: Receive “microgrid mode” command from DSO, REP, or FDEMS Not in IEC 61850 explicitly

Provide black start capabilities

DER system operates as a microgrid (possibly just itself) and supports additional loads being added, so long as they are within its generation range.

Remote: Receive “black start mode” command from DSO, REP, or FDEMS

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Soft-start reconnection

DER system either ramps up when reconnecting or randomly reconnected during a time window.

Autonomous Local: Monitor voltage and frequency at ECP

A.5 Economic Responses Use Cases

Manage energy based on demand response (DR) pricing signals

The DER system receives a demand response (DR) pricing signal from a utility or retail energy provider (REP) for a time period in the future and determines what real power to output at that time.

Remote: Receive DR pricing signal from DSO, REP, or FDEMS

Manage selected ancillary services based on demand response (DR) pricing signals

The DER system receives a demand response (DR) pricing signal from a utility or retail energy provider (REP) for a time period in the future and determines what ancillary services to provide at that time.

Remote: Receive DR pricing signal from DSO, REP, or FDEMS

Provide low-cost energy

DSO, REP, or FDEMS selects which DER systems are to generate how much energy in order to minimize energy costs.

Autonomous Remote: Receive setting for output energy from DSO, REP, or FDEMS

Provide low-emissions energy

DSO, REP, or FDEMS selects which DER systems are to generate how much energy in order to minimize emissions.


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Requirements Provide renewable energy

DSO, REP, or FDEMS selects which DER systems are to generate how much energy in order to maximize the use of renewable energy.


A.6 Wide Area Situational Awareness Use Cases

Provide emergency alarms and information

The DER system provides alarms and supporting emergency information either directly or via the FDEMS to the utility.

Remote: Provide alarms and emergency information to DSO, REP, or FDEMS

Provide status and measurements on current energy and ancillary services

The DER system provides current status, power system measurements, and other real-time data (either directly or via the FDEMS) to the utility. (Metering data is provided via smart meters.)

Remote: Provide status and measurement values to DSO, REP, or FDEMS

Issue generation and storage schedules

The DER system provides schedules of expected generation and storage reflecting customer requirements, maintenance, weather forecasts, etc.

Remote: Provide scheduling information to Utility, REP, or FDEMS

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

The DER system or the FDEMS provides forecast information for available energy and ancillary services over the next hours, days, weeks, etc.

Remote: Provide forecast information to DSO, REP, or FDEMS

A.7 DSO Operational and Planning Use Cases

Perform interconnection information gathering, DER capabilities analysis, and DER impact studies

The utility performs interconnection DER information gathering, DER capabilities analysis, and DER impact studies. The DER information is added to the GIS database, the DERMS database, and other relevant databases. The analysis functions use this DER information to determine what impacts the DER system might have on the grid and vice versa. The utility determines what advanced functions should be activated and what settings should be used for those functions.

Off-line, interfaces with back-office IT systems

System planning involving DER

Includes DER interconnection studies, and other system planning activities taking into account DER capabilities


Operation planning involving DER

Operation planning activities including the reaction and scheduling of DERs


Situational awareness support for area EPS with high penetration of DERs

A DMS application including DER modeling and monitoring Remote monitoring and modeling

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Requirements Integrated Volt/var/Watt Optimization (IVVWO)

A DMS application including DER modeling, monitoring, and control

Remote monitoring and modeling, and remote control

Management of contingencies and feeder reconfiguration

A DMS application including DER modeling, monitoring, and control


Composite load mManagement

Load management including combination of DER, electric storage (ES), microgrids, Demand Response, and IVVWO


A.8 Communications Establishment Use Cases

Provide communication modules

Standard interfaces can connect to wired and/or wireless media. These media could include DSO wireless systems, cellphone GPRS, customer WiFi network, and the Internet.

Remote: Provide communications between the DER system and the DSO (possibly through the customer’s FDEMS)

Support internet protocols

Basic Internet transport layer standards of TCP/IP Remote: Use common transport layer protocols

Provide transport layer security

Basic cybersecurity at the transport layer, such as Transport Layer Security (TLS)

Remote: Provide basic cybersecurity

73



Use standard data models

Abstract data models based on IEC 61850-7-420 and IEC 61850-90-7 for DER systems

Remote: Use interoperable data models, even if mapped to different protocols

Map data models to application protocols

Ability to map the abstract data models to standard protocols, such as ModBus, DNP3, IEC 61850 (MMS), SEP 2.0, etc.

Remote: Permit different protocol mappings

Support user cybersecurity

Basic user-level cybersecurity for user authentication, such as passwords and security certificates

Remote: Require user authentication

A.9 Registration and Maintenance Use Cases

Initiate automated “discovery” of DER systems

The DER system supports its automated “discovery” as interconnected to a location on the power system and initiates the integration process.

Remote: DSO, REP, or FDEMS “discovers” a new or moved DER system

Provide operational characteristics at initial interconnection and upon changes

DER system provides operational characteristics after its “discovery” and whenever changes are made to its operational status.

Off-line or remote: (may be prior to installation) Provide DER characteristics information to DSO, REP, or FDEMS

74


Requirements Test DER software patching and updates

DER software updates are tested for functionality and for meeting regulatory and DSO requirements, including safety.

Off-line, local, or remote: (may be prior to installation or handled locally) Test DER software by DSO, REP, or FDEMS

75


Appendix B. Tentative List of Level 4 and Level 5 T&D Functions and Use Case Scenarios involving DER Systems

Table 2: List of Secondary T&D Functions and Use Case Scenarios involving DER Systems

Group of functions

# Function

Plan

ning

, in

cludi

ng s

afet

y an

d cy

ber-

secu

rity

requ

irem

ents

1. System planning 1 • Electrical interconnection requirements (1547, 1547.7, and 1547.8) 2 • Resource planning 3 • Transmission planning 4 • Distribution planning 5 • Market administration (long-term) 2. Operational planning

6 • Planning maintenance 7 • Planning circuit connectivity 8 • Planning tap positions of distribution transformers and volt/var control

modes and settings 9 • Market administration (short-term)

10 • Planning resources and ancillary services

Mon

itorin

g, a

naly

sis

and

cent

ral c

ontro

l, in

cludi

ng

prov

isio

n of

saf

ety

and

cybe

rsec

urity

1. Situational awareness support for wide area and distribution systems with high penetration of DERs

11 1.1 For transmission domain including aggregated information at substations 12 1.2 For distribution systems with high penetration of DERs 13 1.3 Analysis covering distribution, transmission, and ISO/RTO requirements

2. Integrated Volt/var/Watt Optimization (IVVWO) 2.1. Operating conditions · 2.1.1 Steady-state

14 • Normal 15 • Excessive voltage rise 16 • Reverse power flow

· 2.1.2 Variable conditions 17 • High X/R ratio 18 • Low X/R ratio

2.2. Interactions among themselves and other controllable devices 19 • Low-impedance feeders (stiff circuits) 20 • High-impedance feeders 21 • Different legacy devices and systems

2.3. Cross-cutting over power system domains 22 • EPS-customers 23 • Distribution-Transmission-Generation 24 2.4 Integration of DER, microgrids, and demand response with IVVWO

3. Management of contingencies and feeder reconfiguration 3.1. Distribution contingencies

25 • Inside-feeder event

76


Group of functions

# Function

26 • Outside-feeder event 3.2. Conditions of bulk power contingencies

27 • Under-frequency 28 • Under-voltage 29 • Predictive load shedding 30 • Intentional islanding of bulk power system

3.3. Mutual influences of DER and other devices in abnormal topologies 31 • Reconfigured circuits 32 • Microgrids and islands

4. Load management 33 • DER, electric storage (ES), and microgrids only 34 • Demand response with controllable DER, ES, and microgrids 35 5. Frequency management 36 6. Ancillary services management

77


Appendix C. Examples of the Cross-cutting Gap Analysis

Table 3: Example of Use Cases vs. DER System Categories (Code definitions at end of table)

# DER Categories

Use cases

Lim

it m

axim

um re

al

pow

er o

utpu

t at t

he

PCC

to a

pre

set v

alue

Prov

ide

dyna

mic

re

activ

e po

wer

in

ject

ion

thro

ugh

auto

nom

ous

resp

onse

s to

loca

l vo

ltage

Supp

ort d

irect

co

mm

and

to

disc

onne

ct o

r re

conn

ect

Prov

ide

ride-

thro

ugh

of lo

w/h

igh

volta

ge

excu

rsio

ns b

eyon

d no

rmal

lim

its

Pro

vide

ride

-thro

ugh

of lo

w/h

igh

freq

uenc

y ex

curs

ions

bey

ond

norm

al li

mits

For l

evel

3: (

TBD

)

Dis

trib

utio

n gr

id

man

agem

ent

Adv

ance

d D

istr

ibut

ion

Aut

omat

ion

(AD

A)

fti

D

evel

opm

ent o

f Tr

ansm

issi

on B

us

Load

Mod

el (T

BLM

)

Situ

atio

nal

awar

enes

s fo

r D&

T

1. Categorization as Grid-Connected DER Systems 1 Within virtual power plant ct ct ct ct ct, md, ag,

um ct, md, ag, um

ct, md, ag, um

2 Within a substation mo, cc mo, cc mo, cc 3 Within a residence md md md 4 Within a real power plant like a

wind farm mo, cc mo, cc mo, cc

5 Within a military environment ct ct ct, md, ag, um

ct, md, ag, um

ct, md, ag, um

6 Within a distribution feeder as a stand-alone DER or group of DERs as a distribution-connected power plant

mo, cc mo, cc mo, cc

7 Within a community ct ct, md, ag, um

ct, md, ag, um

ct, md, ag, um

8 Within a campus environment ct ct, md, ag, um

ct, md, ag, um

ct, md, ag, um

9 Within a building (office, apartment, commercial, industrial)

ct, md ct, md ct, md

78


# DER Categories

Use cases

Lim

it m

axim

um re

al

pow

er o

utpu

t at t

he

PCC

to a

pre

set v

alue

Prov

ide

dyna

mic

re

activ

e po

wer

in

ject

ion

thro

ugh

auto

nom

ous

resp

onse

s to

loca

l vo

ltage

Supp

ort d

irect

co

mm

and

to

disc

onne

ct o

r re

conn

ect

Prov

ide

ride-

thro

ugh

of lo

w/h

igh

volta

ge

excu

rsio

ns b

eyon

d no

rmal

lim

its

Pro

vide

ride

-thro

ugh

of lo

w/h

igh

freq

uenc

y ex

curs

ions

bey

ond

norm

al li

mits

For l

evel

3: (

TBD

)

Dis

trib

utio

n gr

id

man

agem

ent

Adv

ance

d D

istr

ibut

ion

Aut

omat

ion

(AD

A)

fti

D

evel

opm

ent o

f Tr

ansm

issi

on B

us

Load

Mod

el (T

BLM

)

Situ

atio

nal

awar

enes

s fo

r D&

T

2. Categorization as Logical and/or Islanded Microgrids 10 Transitions between grid-

connected and islanded, including UPS systems for backup

mo, ct, md mo, ct, md mo, ct, md

11 Pre-planned microgrid with combined management and autonomous

ct ct, md, ag, um

ct, md, ag, um

ct, md, ag, um

12 Multiple logical and/or islanded microgrid monitoring and analysis (e.g., networked microgrids or meshed microgrids or active distribution networks)

ag, mo, ct, md, cc, um



13 Emergency microgrid with after-the-fact management




14 Autonomous decentralized control

ag, md, um ag, md, um ag, md, um

15 As permanent island ag, md, um ag, md, um ag, md, um

16 As backup for any configuration ag, md, um ag, md, um ag, md, um

17 AC vs. DC microgrids, including combinations of AC and DC

md, um md, um md, um

3. Categorization by Management Authority 18 Private customer ct md, um md, um md, um

79


# DER Categories

Use cases

Lim

it m

axim

um re

al

pow

er o

utpu

t at t

he

PCC

to a

pre

set v

alue

Prov

ide

dyna

mic

re

activ

e po

wer

in

ject

ion

thro

ugh

auto

nom

ous

resp

onse

s to

loca

l vo

ltage

Supp

ort d

irect

co

mm

and

to

disc

onne

ct o

r re

conn

ect

Prov

ide

ride-

thro

ugh

of lo

w/h

igh

volta

ge

excu

rsio

ns b

eyon

d no

rmal

lim

its

Pro

vide

ride

-thro

ugh

of lo

w/h

igh

freq

uenc

y ex

curs

ions

bey

ond

norm

al li

mits

For l

evel

3: (

TBD

)

Dis

trib

utio

n gr

id

man

agem

ent

Adv

ance

d D

istr

ibut

ion

Aut

omat

ion

(AD

A)

fti

D

evel

opm

ent o

f Tr

ansm

issi

on B

us

Load

Mod

el (T

BLM

)

Situ

atio

nal

awar

enes

s fo

r D&

T

19 Virtual power plant (VPP) ct ag, ct, md, um

ag, ct, md, um

ag, ct, md, um

20 Utility with direct control mo, cc mo, cc mo, cc 21 Retail energy providers (REP) ct ag, ct, md,

um ag, ct, md, um

ag, ct, md, um

22 Demand response and other financial signals

ct, md, um ct, md, um ct, md, um

23 Cooperative control between customer and utility

ct ag, ct, md, um

ag, ct, md, um

ag, ct, md, um

4. Categorization by Communications Capabilities 24 Autonomous no monitoring, no

control ct, md, um ct, md, um ct, md, um

25 Autonomous no monitoring, with broadcast instructions and decentralized control

mo, ct, md, us, um

mo, ct, md, us, um

mo, ct, md, us, um

26 Autonomous no monitoring, with decentralized control

ct, md, us, um

ct, md, us, um

ct, md, us, um

27 Autonomous with monitoring and decentralized control

mo, ct, md, um

mo, ct, md, um

mo, ct, md, um

28 Autonomous with monitoring, no control

mo, ct, md, um

mo, ct, md, um

mo, ct, md, um

29 With near-real-time monitoring, direct communications and autonomous control

mo, ct, md, us, um

mo, ct, md, us, um

mo, ct, md, us, um

80


# DER Categories

Use cases

Lim

it m

axim

um re

al

pow

er o

utpu

t at t

he

PCC

to a

pre

set v

alue

Prov

ide

dyna

mic

re

activ

e po

wer

in

ject

ion

thro

ugh

auto

nom

ous

resp

onse

s to

loca

l vo

ltage

Supp

ort d

irect

co

mm

and

to

disc

onne

ct o

r re

conn

ect

Prov

ide

ride-

thro

ugh

of lo

w/h

igh

volta

ge

excu

rsio

ns b

eyon

d no

rmal

lim

its

Pro

vide

ride

-thro

ugh

of lo

w/h

igh

freq

uenc

y ex

curs

ions

bey

ond

norm

al li

mits

For l

evel

3: (

TBD

)

Dis

trib

utio

n gr

id

man

agem

ent

Adv

ance

d D

istr

ibut

ion

Aut

omat

ion

(AD

A)

fti

D

evel

opm

ent o

f Tr

ansm

issi

on B

us

Load

Mod

el (T

BLM

)

Situ

atio

nal

awar

enes

s fo

r D&

T

30 With near-real-time monitoring, direct communications and central control (DMS)

mo, ct, md, us, um

mo, ct, md, us, um

mo, ct, md, us, um

5. Categorization by Management 31 Utility-controlled and/or indirectly

managed mo, md,

us, um mo, md, us,

um mo, md, us, um

32 Microgrids (financial and islanded)

ct ag, mo, ct, md, us, um

ag, mo, ct, md, us, um

ag, mo, ct, md, us, um

33 Actual power plant such as a wind farm, which may be managed by a third party or by distribution utility

ct mo, md, us, um

mo, md, us, um

mo, md, us, um

6. Categorization by Type of DER 34 Composite DER

Applicability according to the categories above

34 Synchronous generation 35 EV 36 Fuel cell w/o var capabilities 37 Fuel cell with var capabilities 38 Micro-turbines 39 Solar w/o var capabilities 40 Solar with var capabilities 41 Storage w/o var capabilities

81


# DER Categories

Use cases

Lim

it m

axim

um re

al

pow

er o

utpu

t at t

he

PCC

to a

pre

set v

alue

Prov

ide

dyna

mic

re

activ

e po

wer

in

ject

ion

thro

ugh

auto

nom

ous

resp

onse

s to

loca

l vo

ltage

Supp

ort d

irect

co

mm

and

to

disc

onne

ct o

r re

conn

ect

Prov

ide

ride-

thro

ugh

of lo

w/h

igh

volta

ge

excu

rsio

ns b

eyon

d no

rmal

lim

its

Pro

vide

ride

-thro

ugh

of lo

w/h

igh

freq

uenc

y ex

curs

ions

bey

ond

norm

al li

mits

For l

evel

3: (

TBD

)

Dis

trib

utio

n gr

id

man

agem

ent

Adv

ance

d D

istr

ibut

ion

Aut

omat

ion

(AD

A)

fti

D

evel

opm

ent o

f Tr

ansm

issi

on B

us

Load

Mod

el (T

BLM

)

Situ

atio

nal

awar

enes

s fo

r D&

T

42 Storage with var capabilities 43 Wind

Codes:

Characteristic of data: ns – not provided by object model standards md – modeling data required ag – aggregated data al - disaggregated or allocated data ct - contractual or market data tb - TBLM data Type of data: cc - control command

us - updated settings mo - monitored data as - assessment/analysis um - needs updates of object model Existence/usage of relevant standards 61 - 61850 CM - CIM DN - DNP3 AN - ANSI C12.x

82

Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models Table 4: Step-by-Step Activities vs. DER Categories (Excerpts from the Distribution Grid Management Use Case [5])

Codes: Characteristic of data: ns – not provided by object model standards md – modeling data required ag – aggregated data al - disaggregated or allocated data ct - contractual or market data tb - TBLM data Type of data: cc - control command us - updated settings mo - monitored data as - assessment/analysis um - needs updates of object model Existence/usage of relevant standards 61 - 61850 CM - CIM DN - DNP3 AN - ANSI C12.x

Categorization as Grid-Connected DER Systems Categorization as Logical and/or Islanded Microgrids Categorization by Communications Capabilities

Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)

Event Additional Notes

DMS Scheduler polls DSCADA and other databases for data relevant to DMS. Addition: "and other data management system"

Data include analogs, statuses, and tabular data collected by DSCADA from remotely monitored devices in distribution and stored in DSCADA’s database and by other communication means and stored in other databases, such as DER/microgrid Data Management System, DER/microgrid Model Processor, AMI Data Management System (e.g., outage detections).

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

al, u

s, m

o, C

M

md,

al,

as, u

m, C

M

al, u

s, m

o, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

al, u

s, m

o, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

md,

al,

mo,

as,

um

, CM

md,

ag,

al,

ct, u

s, m

o, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

al,

as, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, m

o, a

s, u

m, C

M

md,

al,

us, m

o, a

s, u

m, C

M

md,

al,

us, m

o, a

s, u

m, C

M

al, u

s, m

o, u

m, C

M

1. Some VPP DERs have DSCADA capabilities, some don’t.

2. Should include relevant data from the TBLM; needs model updates from not monitored objects.

3. Modeling of non-monitored parameters is performed in the DER model processor of DMS (part of DERMS). DMS Scheduler communicates with the DER model processor via CIM (or MultiSpeak).

DMS Scheduler polls EMS/SCADA database for data relevant to DMS.

Data include analog and statuses collected by EMS/SCADA from substations and data from EMS and MOS applications via the TBLM.

Applicable to all: the EMS/SCADA data presented in the TBLM for the use by the DMS may change the outcome of the DMS applications, which take into account the measurements and the models of all components of the distribution system and alter some of them. (ct, tb, cc (requests), us, mo, um, CM)

DMS Scheduler polls external system databases for data relevant to DMS.

Data include current and forecast weather data by relevant areas.

Applicable to all (ns, al, tb, um, CM)

83




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


Last snapshot received by DMS Scheduler.

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

al, u

s, m

o, C

M

md,

al,

as, u

m, C

M

al, u

s, m

o, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

al, u

s, m

o, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

md,

al,

mo,

as,

um

, CM

md,

ag,

al,

ct, u

s, m

o, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

al,

as, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, m

o, a

s, u

m, C

M

md,

al,

us, m

o, a

s, u

m, C

M

This snapshot includes all components obtained in the previous steps. Updates of models of non-monitored objects are needed. These updates include the current states of the object and the availability for changes, which in turn should take into account contractual conditions, if a third party is involved. That means that additional actors and/or object models may be needed.

There are changes of statuses in distribution and/or there are changes of external data in the consolidated snapshot, or it is the time for a periodic run of an application. No fault indicators either from field IEDs, or from AMI.

Applicable to all (md, ag, al, ct, tb, cc, us, mo, as, um, CM) Or there are changes in the models of non-monitored objects.

DOMA received the command to start.

Applicable to all (md, ag, al, ct, tb, cc, us, mo, as, um, CM) Distribution Operation Model and Analysis (DOMA) includes all components - monitored and modeled. Some models are adjusted to the power flow modeling results (iteratively), e.g., due to the DER capability curves, which are dependent on voltage.

84




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


DOMA finished updates of the models.

Applicable to all (md, ag, al, ct, tb, cc, us, mo, as, um, CM) The nominal models are adjusted to the power flow conditions.

DOMA finished run, publishes results, and initiates TBLM developer.

Applicable to all (md, ag, al, ct, tb, cc, us, mo, as, um, CM) Additional actor and steps are needed to update the TBLM.

DMS Scheduler received an update of situational awareness of distribution operations.

Applicable to all (md, ag, al, ct, tb, cc, us, mo, as, um, CM) It may include aggregated data for entities which include combined DER and loads. Additional actor and steps are needed to update the TBLM.

DMS Scheduler received the flag on IVVWO readiness.

Applicable to all

IVVWO received a command to start.

Applicable to all

IVVWO completed the calculations.

The first group of commands can be executed at the same time or in any order. The second group of commands can be executed only after the first group is successfully executed, etc.

Applicable to all (md, ag, al, ct, tb, us, mo, as, um, CM) IVVWO performs based on all components of the distribution model and automatically adjusts controllable and dependable components to the new voltages.

85




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


DMS Scheduler received IVVWO output with new setpoints and transmits the setpoints and requests to the corresponding devices and systems.

The first group of commands can be executed at the same time or in any order. The second group of commands can be executed only after the first group is successfully executed, etc.

Applicable to all (md, ag, al, ct, tb, cc, us, mo, as, um, CM, 61) The new setpoints/requests are applicable to the EPS volt/var controlling devices, to demand response installations, and to DER/micro-grids with the ability of volt/var control. Some of the commands/requests can be directed to customer/microgrid EMS.

Load Management received a request to enable particular demand response means and transmits the requests to the DR installations.

It can be a price signal or another agreed upon (contractual) demand response trigger and an array of DR attributed. The behavioral load models including DR are dependent on execution patterns of DR installations. m

d, a

g, a

l, ct

, us,

mo,

as,

um

, CM

md,

al,

as, u

m, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

md,

al,

mo,

as,

um

, CM

md,

ag,

al,

ct, u

s, m

o, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

al,

as, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, m

o, a

s, u

m, C

M

md,

al,

us, m

o, a

s, u

m, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

al, u

s, m

o, C

M

IVVWO solution may include requests for DR. There are many different programs for DR, i.e., the model objects should cover many possible programs.

DER/microgrid Management system received request for DER/microgrid control means and transmits the requests to the DER installations.

It can be a price signal or another agreed upon DER control trigger, or a mode of var control, or a setpoint for Watt and for var control. In case of many small DERs with the ability of var control, the request is issued to clusters of many.

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

cc, 6

1

md,

al,

as, u

m, C

M

cc, 6

1

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

cc, 6

1

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m, C

M

md,

al,

mo,

as,

um

, CM

md,

ag,

al,

ct, u

s, m

o, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

al,

as, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, a

s, u

m, C

M

cc, 6

1

cc, 6

1

cc, 6

1

cc, 6

1

For DER systems, it may need to go through a third party, which means additional steps are needed. Timing may be different. Microgrid EMS receives IVVWO requests attributed to the PCC and finds a solution within the microgrid to meet the request, performing its internal IVVWO. For autonomous microgrids, other non-standard communication means can be used, e.g., e-mails.

86




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


DMS Scheduler received snapshots/messages confirming the execution of the first group of commands.

The confirmation of acceptance and execution by different devices can come in different snapshots. A waiting time for collecting the confirmation should be assigned.

Applicable to all It may be snapshots of measurements and model updates. The reports of execution of the commands/requests may have different formats for different controllable means. For instance, the report on execution of a request by a composite entity may include accompanying messages.

DMS Scheduler received IVVWO output with the second set of setpoints and requests.

In case, the previous set of setpoints and requests was not the final.

Applicable to all (md, ag, al, ct, tb, cc, us, mo, as, um, CM 61,) The setpoints may include the settings of the LTC controllers, capacitor statuses, DER modes of operation and settings, DR requests, and IVVWO requests directed to customer/microgrid EMS.

DOMA receives confirmation of enabling the DR.

The behavioral load models including DR are dependent on the demand response triggers and on other external conditions. The actual execution of DR and the reports on the executions may take time and will be far after the fact.

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

al,

as, u

m, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

al,

mo,

as,

um

, CM

md,

ag,

al,

ct, u

s, m

o, u

m,

CM

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

al,

as, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, m

o, a

s, u

m, C

M

md,

al,

us, m

o, a

s, u

m, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

al, u

s, m

o, C

M

DOMA updates the load models for the current and near-look-ahead times based on the load dependencies on the external factors and available statistics of DR execution.

87




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


DOMA receives confirmation of enabling the DER.

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

mo,

61

md,

al,

as, u

m, C

M

mo,

61

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

mo,

61

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

al,

mo,

as,

um

, CM

md,

ag,

al,

ct, u

s, m

o, u

m,

CM

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

al,

as, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, a

s, u

m, C

M

mo,

61

mo,

61

mo,

61

mo,

61

IVVWO received a new base case.

Applicable to all (md, ag, al, ct, tb, mo, as, um, CM) It includes new DOMA outputs, such as new load models, DER capability curves, microgrid dispatchable real and reactive load, new aggregated at PCCs load-to-voltage dependencies, etc. New object models may be needed. The new base case may be different from the one assumed by IVVWO during the previous optimization.

IVVWO finished runs on the updated model and submits the solution to the DMS scheduler.

Applicable to all (md, ag, al, ct, tb, us, mo, as, um, CM)

88




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


DMS Scheduler received IVVWO output with new setpoints and statuses and transmits the setpoints and requests to the corresponding devices and systems.

Applicable to all (md, ag, al, ct, tb, cc, us, mo, as, um, CM, 61)

DMS Scheduler received information on failure of execution of one or more issued commands.

Applicable to all (md, ag, al, ct, tb, us, mo, as, um, CM, 61) Or a refusal by a third party to execute. In these cases, IVVWO re-optimizes the solution with new variables and constraints.

IVVWO received a change on availability of controllable devices.

Repeat the previous IVVWO steps.

In these cases, IVVWO re-optimizes the solution with new variables and constraints.

89




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


A circuit breaker (feeder recloser) opened and locked out.

DMS Scheduler analyzes the snapshots for indications of a sustained outage, and, if it is present, triggers FLIR. The Distributed Intelligence schemes, if any, start operating.

Applicable to all, except within a substation

DOMA received a change of statuses.

DOMA runs with new data and submits the new operation model to other DMS applications.

Applicable to all, except within a substation The information about the change of DER statuses can be received through direct communications, if available, and/or through modeling the behavior of DER based on the available information in the DER management system.

IVVWO received new operation model.

IVVWO runs based on the new operation model and issues commands/requests to the corresponding controllable devices to adjust the optimal Volt/var/Watt to the new conditions.

Applicable to all The IVVWO actions include: a) the first iteration decision-making assuming the execution of the commands/requests to the controllable devices and taking into account the reactions of all devices based on available modeling; b) issuing the commands/requests to corresponding devices; c) receiving the results of execution; d) the next iteration, if needed.

90




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


The results of execution can be determined based on direct communications, if available, and/or on the analyses of the new operating conditions by using a state-estimation like application that includes models of the non-observable parameters.

DMS Scheduler received a report, from DOMA and IVVWO, that no overload or intolerable voltage violations are expected during the time of repair of the faulted facility.

Applicable to all No actions needed.

DMS Scheduler received a report, from DOMA and IVVWO, on an overload or an intolerable voltage violation during the time of repair of the faulted facility.

Applicable to all A centralized review of the contingency situation may be required to find other solutions for restoration, e.g., multi-level feeder reconfiguration, which may require a significant computation power, especially with multiple DERs and DR involved.

91




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


Multi-level Feeder Reconfiguration (MFR) receives a command to start with the objective of load balancing to eliminate overloads.

Applicable to all The initial model to be used by MFR should be updated by the current states and capabilities of the DERs in the subject feeders.

MFR runs optimization.

Applicable to all

DMS/Operator receives a new switching sequence and other instructions and issues a switching order and instructions to the actuators.

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

cc, 6

1

md,

al,

as, u

m, C

M

cc, 6

1

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

cc, 6

1

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

al,

mo,

as,

um

, CM

md,

ag,

al,

ct, u

s, m

o, u

m,

CM

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

al,

as, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, a

s, u

m, C

M

cc, 6

1

cc, 6

1

cc, 6

1

cc, 6

1

The solution includes changes of statuses of switching devices for paralleling feeders and transfers of feeder sections, as well as changes of statuses and/or modes of operations of DER and microgrids. It may also take into account contractual conditions of third parties.

92




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


DMS/Operator receives a message from MFR that no solution of unloading the overloaded feeder is found and starts IVVWO again.

It implies that IVVWO will enable DR to unload the overloaded segments.

MFR in coordination with IVVWO finds a solution with Demand response

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

al,

as, u

m, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

al,

mo,

as,

um

, CM

md,

ag,

al,

ct, u

s, m

o, u

m,

CM

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

al,

as, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, m

o, a

s, u

m, C

M

md,

al,

us, m

o, a

s, u

m, C

M

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

al, u

s, m

o, C

M

DMS/Operator receives a new switching sequence and other instructions and issues a switching order and instructions to the actuators.

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

cc, 6

1

md,

al,

as, u

m, C

M

cc, 6

1

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

cc, 6

1

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

al,

mo,

as,

um

, CM

md,

ag,

al,

ct, u

s, m

o, u

m,

CM

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

al,

as, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, a

s, u

m, C

M

cc, 6

1

cc, 6

1

cc, 6

1

cc, 6

1

93




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


DMS/Operator receives a message that no solution of unloading the overloaded feeder, even with DR, is found and starts Service Restoration sub-function with the intent to leave some sections de-energized.

md,

ag,

al,

ct, u

s, m

o, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

cc, 6

1

cc, 6

1

cc, 6

1

cc, 6

1

It may include disconnection of some load-rich microgrids from the EPS.

DMS/Operator receives a new switching sequence and other instructions and issues a final switching order and instructions to the actuators.

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

cc, 6

1

md,

al,

as, u

m, C

M

cc, 6

1

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

cc, 6

1

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

ag,

al,

ct, u

s, m

o, a

s, u

m,

CM

md,

al,

mo,

as,

um

, CM

md,

ag,

al,

ct, u

s, m

o, u

m,

CM

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

ag,

ct,

us, a

s, u

m, C

M

md,

al,

as, u

m, C

M

md,

al,

us, a

s, u

m, C

M

md,

al,

us, a

s, u

m, C

M

cc, 6

1

cc, 6

1

cc, 6

1

cc, 6

1

94




Additional Comments

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of D

ERs

as a

di

tib

tit

d

lt

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, apa

rtmen

t, co

mm

erci

al, i

ndus

trial

)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous

dece

ntra

lized

con

trol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of

AC

and

DC

Aut

onom

ous

no m

onito

ring,

no

cont

rol

Aut

onom

ous

no m

onito

ring,

with

br

oadc

ast i

nstru

ctio

ns a

nd d

ecen

traliz

ed

cont

rol

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Aut

onom

ous

with

mon

itorin

g, n

o co

ntro

l

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral c

ontro

l (D

MS)


Microgrid EMS reports a change in the generation - load composition.

Updates of aggregated load-to-voltage/frequency dependencies; capability curves, dispatchable load; other attributes of the aggregated microgrid model. Data is received by the microgrid data management system. The microgrid model processor retrieves relevant data from the data management system and updates the components of the aggregated model.

md, ag, ct, mo, as, um, CM Other components of the model may include the participation and settings of RAS within the microgrid and at PCC, DER protection settings, overlaps of different load management means, changes in values and conditions of Demand Response, etc.

DMS Scheduler issues a command to start TBLM developer.

The TBLM developer initiates the runs of relevant DMS applications in a study mode to develop the update of the TBLM, based on changes of statuses, analogs, and states of aggregated data from microgrid EMS, VPPs, customer EMS, DER, and DR models.

Applicable to all that presented significant changes. (md, ag, al, ct, tb, cc, us, mo, as, um, CM)

95


Appendix D. Example of Gap Analysis for Levels 1, 2, and 3 of the DER Volt-Var Use Case

Table 5: Example of Gap Analysis for Levels 1, 2, and 3 of the DER Volt-Var Use Case Steps

Char

acte

ristic

s of D

ata

Type

of D

ata

With

in v

irtua

l pow

er p

lant

With

in a

subs

tatio

n

With

in a

resid

ence

With

in a

real

pow

er p

lant

like

a w

ind

farm

With

in a

mili

tary

env

ironm

ent

With

in a

dist

ribut

ion

feed

er a

s one

or m

ore

DERs

as a

dist

ribut

ion-

conn

ecte

d pl

ant

With

in a

com

mun

ity

With

in a

cam

pus e

nviro

nmen

t

With

in a

bui

ldin

g (o

ffice

, apa

rtm

ent,

com

mer

cial

, ind

ustr

ial)

Pre-

plan

ned

mic

rogr

id w

ith c

ombi

ned

man

agem

ent a

nd a

uton

omou

s

Auto

nom

ous d

ecen

tral

ized

cont

rol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. DC

mic

rogr

ids,

incl

udin

g co

mbi

natio

ns o

f AC

and

DC

Priv

ate

cust

omer

with

com

plet

e co

ntro

l

Virt

ual P

ower

Pla

nt (V

PP)

Utili

ty w

ith d

irect

con

trol

Reta

il en

ergy

pro

vide

rs (R

EP)

Coop

erat

ive

Cont

rol b

etw

een

Cust

omer

an

d Ut

ility

Auto

nom

ous n

o m

onito

ring,

no

cont

rol

Auto

nom

ous n

o m

onito

ring,

bro

adca

st

inst

ruct

ions

and

dec

entr

alize

d co

ntro

l

Auto

nom

ous n

o m

onito

ring,

with

de

cent

raliz

ed c

ontr

ol

Aut

onom

ous w

ith m

onito

ring

and

dece

ntra

lized

con

trol

Aut

onom

ous w

ith m

onito

ring,

no

cont

rol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

aut

onom

ous c

ontr

ol

With

nea

r-rea

l-tim

e m

onito

ring,

dire

ct

com

mun

icat

ions

and

cen

tral

con

trol

(DM

S)

Util

ity-C

ontr

olle

d an

d/or

Indi

rect

ly

Man

aged

Mic

rogr

ids (

Fina

ncia

l and

Isla

nded

)

Act

ual p

ower

pla

nt su

ch a

s a w

ind

farm

, w

hich

may

be

man

aged

by

a th

ird p

arty

or

by d

istrib

utio

n ut

ility

Com

posit

e DE

R Sy

stem

Sync

hron

ous g

ener

ator

s

Indu

ctan

ce g

ener

ator

s suc

h as

win

d

Mic

rotu

rbin

es w

ith sm

art i

nver

ter

bili

iPV

with

smar

t inv

erte

r cap

abili

ties

Ener

gy st

orag

e w

ith sm

art i

nver

ter

bili

iFu

el c

ell w

ith sm

art i

nver

ter c

apab

ilitie

s

Elec

tric

Veh

icle

EV

with

V2G

cap

abili

ties

PV w

/o sm

art i

nver

ter c

apab

ilitie

s

Fuel

cel

l w/o

smar

t inv

erte

r cap

abili

ties

Ener

gy st

orag

e w

/o sm

art i

nver

ter

bili

i

Sending Actor Receiving Actor Action

DSO DER owner

During interconnection analysis, DSO determines that DER system must include volt-var function to be optionally activated

nsMost likely this will be an off-line process

DSO DERMS DSO DMS DSO DERMS provides DER data to DSO DMS for analysis to determine what volt-var settings should be required

md as CIM up ex no ex no no no no no no no no no no no ex no no no no no no no no no no no no no no no no no no no no no no no

CIM modeling of transmission-connected DER exists; no adequate CIM modeling of distribution-connected DER

DSO DER owner DSO DMS sends the appropriate default volt-var mode settings, plus two additional available volt-var mode settings for different situations

md us61, DNP,

XMLex ex ex ex ex ex ex ex ex up ex ex

ex or up?

ex ex ex ex ex ex ex ex ex ex ex ex ex ex up ex up up ex up up up

IEC 61850 models for volt-var exist for most situations, but might need updating for microgrids and DC/AC

i idDSO DER Operator DSO requests the DER operator to activate the default volt-var mode in all DER systems that are capable

ag cc61, DNP,


ex or up?


DER operator FDEMS DER management system

DER operator commands the FDEMS to activate volt-var modes in all capable DER systems

ag us61, DNP,


ex or up?


FDEMS DER management system

DER system FDEMS determines which DER systems are volt-var capable, and activates the volt-var mode in those DER systems (allocates the volt-var function). May use transactive energy signals rather than control commands.

al us61, Mod, BAC, SEP,

ADRex ex ex ex ex ex ex ex ex up ex ex

ex or up?


IEC 61850 models exist, but mappings to ModBus & SEP 2 need testing. Mapping to BACmet does not exist. OpenADR for DER services are not complete (IEC TC57 WG21 is working on this)

DER system FDEMS DER management system

Each DER system sends an event notification to the FDEMS when it modifies its vars in response to voltage changes

al mo61, Mod, BAC, SEP,

ADRex ex ex ex ex ex ex ex ex up ex ex no ex ex ex ex ex ex ex ex ex ex ex ex ex ex up ex up up ex up up up

FDEMS DER management system

DSO FDEMS aggregates the var amounts from each of the DER systems and provides this aggregated var amount to the DSO

ag mo61, DNP,

XMLup up up up up up up up up up up up no up up up up up up up up up up up up up up up ex up up ex up up up

Aggregation information models need to be improved or created (IEC 61850-90-15)

DSO DERMS DSO DMS DSO DERMS provides DER data to DSO DMS for analysis to determine whether volt-var settings might be modified or not

md as CM no ex no ex no no no no no no no no no no no ex no no no no no no no no no no no no no no no no no no no no no no no

Requirements by CIM for aggregated data is starting to be developed, but no CIM models exist yet (IEC 61850 - CIM Harmonization)

Codes:Characteristics of data ns – not provided by object model standards md – modeling data ag – aggregated data al - disagregated or allocated data ct - contractual or market dataType of data cc - control command us - updated settings mo - monitored data as - assessment/analysisExistence/usage of relevant standards 61 - 61850 CIM - CIM C12 - ANSI C12.x DNP - DNP3 Mod - ModBus BAC - BACnet SEP - SEP 2.0 ADR - OpenADR Oth - Other

Categorization by Communications Capabilities

Categorization by Management

Add

ition

al C

omm

ents

Use Case for Volt-Var Function

The DER system provides volt-var management through “curves” that define the reactive power for different voltage values above and below the desired voltage level. The purpose is to use vars to counteract deviations in voltage, with the goal of keeping voltage close to the desired voltage level.

ex - standard exists for the step shownno - standard does not exist but ought toup - standard exists but needs updating"blank" - no standard needs to exist

Categorization as Grid-Connected DER Systems

Categorization as Logical and/or

Islanded Microgrids

Categorization by Management

AuthorityCategorization by Type of DER

Exist

ence

/usa

ge o

f rel

evan

t com

mun

icat

ion

stan

dard

s

96

Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models Table 6: Actors vs. DER Categories (Code: r - relevant)

Actors

Actor’s functionalities

DER categories

Comments/Additional functionalities

Actors in the reference use case:

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a

win

d fa

rm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of

DER

s as

a d

istri

butio

n-co

nnec

ted

pow

er p

lant

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, ap

artm

ent,

com

mer

cial

, in

dust

rial)

Pre-

plan

ned

mic

rogr

id w

ith

com

bine

d m

anag

emen

t and

au

tono

mou

s

Auto

nom

ous

dece

ntra

lized

co

ntro

l

As b

acku

p fo

r any

co

nfig

urat

ion

Distribution Operator

The operator sets up the DMS applications, defining the objectives, the modes of operations, the contents of application results presented to the operator; provides certain input data; monitors the results of DMS applications; requests additional information, when needed; authorizes the DMS recommendations; makes decisions based on DMS recommendations, etc. Normally, the operator defines the options for the close-loop control in advance, but does not take a part in the close-loop control.

Applicable to all categories

Additional functionalities: Communicates with VPP operator/management systems; with community, campuses, and aggregator management systems, issues requests and schedules for autonomously controlled DER; issues requests, schedules and/or commands to microgrid EMS, receives, analyzes and takes into account.

Distribution SCADA

DSCADA collects data from IEDs beyond the fence of the T&D substation and supports remote control of controllable devices in the field either in supervisory or close-loop modes. The field IEDs include utility DER and microgrid controllers, may include customer EMS. Distribution SCADA database is a major source of input data for the DMS applications. It is updated via remote monitoring and operator inputs. DSCADA is used for execution of DMS application solutions either in supervisory, or in close-loop modes.

r r r r Additional functionalities: Communicates with microgrid and other collective EMS receiving aggregated data and issuing commands/requests.

Transmission SCADA/EMS

Transmission and generation management system provides DMS with transmission/generation-related objectives, constraints, and input data. EMS contains the transmission power system model, and can provide the transmission connectivity information for facilities in the vicinity of the distribution power system facilities and with outputs from other EMS applications.

Applicable to all categories via aggregated models of TBLM

Additional functionalities:

Includes in the EMS applications aggregated models of distribution operations including near-real-time and short-term look ahead models of DER, Demand Response, RAS, and other relevant components of distribution operations. EMS communicates in two-way manner with DMS via TBLM.

Microgrid EMS Calculates, stores, and communicates aggregated load, Demand Response, generation data for the microgrid, protection settings and settings for frequency and voltage control for connected and for autonomous modes of operations, other data needed for current and predictive model of microgrid operations.

r r r

Additional Actors:

97


Actors

Actor’s functionalities

DER categories

Comments/Additional functionalities

Actors in the reference use case:

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a

win

d fa

rm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of

DER

s as

a d

istri

butio

n-co

nnec

ted

pow

er p

lant

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, ap

artm

ent,

com

mer

cial

, in

dust

rial)

Pre-

plan

ned

mic

rogr

id w

ith

com

bine

d m

anag

emen

t and

au

tono

mou

s

Auto

nom

ous

dece

ntra

lized

co

ntro

l

As b

acku

p fo

r any

co

nfig

urat

ion

VPP Management system

Calculates, stores, monitors, and communicates the current and look-ahead aggregations of the Distributed Generation, Demand Response, and microgrids. Interfaces with distribution and transmission domains entities and trades with market domain.

r

Community EMS Communicates with Data Management System of DMS or other systems dedicated to manage aggregated generation and loads and with DMS applications. Supports control of frequency and voltages either in autonomous mode, or controlled by the community EMS.

r

Campus EMS Communicates with Data Management System of DMS or other systems dedicated to manage aggregated generation and loads and with DMS applications. Supports control of frequency and voltages either in autonomous mode, or controlled by the campus EMS.

r

Microgrid Data Management System.

A specific database for microgrid attributes, adaptation models, contracts, and performance associated with the EPS and microgrid interactions.

r r r Microgrid data management system is interfaced with other Data Management Systems, Aggregators, with the Load Management System, and with the ADA applications incorporating microgrid adaptive models.

Microgrid Model Processor

Develops adaptive models of microgrids based on new data obtained from the snapshots of the DMS scheduler and attributes from the Data Management System.

r r r

98

Distributed Energy Resources (DER): Hierarchical Classification of Use Cases and the Process for Developing Information Exchange Requirements and Object Models Table 7. Interfaces vs. DER Categories (Definitions of codes at the end)

Source of Information

Recipient of

information Categorization as Grid-Connected DER Systems


Islanded Microgrids


Comments

Contents of information

Type

of d

ata:

Char

acte

ristic

of d

ata:

Exis

tenc

e/us

age

of re

leva

nt

stan

dard

s:

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a

win

d fa

rm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of

DER

s as

a d

istri

butio

n-co

nnec

ted

pow

er p

lant

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, ap

artm

ent,

com

mer

cial

, in

dust

rial)

Pre-

plan

ned

mic

rogr

id w

ith

com

bine

d m

anag

emen

t and

t

Au

tono

mou

s de

cent

raliz

ed

cont

rol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of A

C a

nd D

C

Auto

nom

ous

no m

onito

ring,

no

cont

rol

Auto

nom

ous

no m

onito

ring,

br

oadc

ast i

nstru

ctio

ns a

nd

dli

d l

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g, n

o t

l W

ith n

ear-r

eal-t

ime

mon

itorin

g,

dire

ct c

omm

unic

atio

ns a

nd

Smart Meter or equivalent

device

AMI/DER/ DR Data

Management Systems

Interval net kW and kvar of DER cl

vario

us

AN

ag

mo,

al

md

mo,

al

mo,

ag,

md

(if

not m

o)

mo,

al

mo,

ag,

md

(if

not m

o)

mo,

ag,

md

(if

not m

o)

md

mo,

ag,

md

(if

not m

o)

ag, m

d

md

md

md

mo,

cl

mo,

cl

mo,

cl

Net metering masks DER behavior. Separate load and DER data are needed for adequate load-to-voltage and load-to-frequency dependencies.

kWh of DER

Cl

vario

us

AN

ag

mo,

al

md

mo,

al

mo,

ag,

md

(if n

ot m

o)

mo,

al

mo,

ag,

md

(if n

ot m

o)

mo,

ag,

md

(if n

ot m

o)

md

mo,

ag,

md

(if n

ot m

o)

ag, m

d

md

md

md

mo,

cl

mo,

cl

mo,

cl

Some of this data will not come directly from the smart meter, but from a processor of the smart meter data and other sources.

Real and reactive load profiles of DER

cl

ar

AN

ag

mo,

cl

md

mo,

cl,

md

(if

not m

o)

mo,

cl,

md

(if

not m

o)

mo,

cl

mo,

cl,

md

(if

not m

o)

mo,

cl,

md

(if

not m

o)

md

mo,

cl,

md

(if

not m

o)

ag,

cl

md

md

md

mo,

md

mo,

md

mo,

cl

Interval average voltages

Cl

vario

us

AN

as

al

cl

al

as

mo as

as

cl

as

md

md

md

md

mo

mo

mo,

cl

Selected critical voltages from DER-Load aggregations represented in the EMS of aggregations.

Weather data cl

ar

AN

as

mo,

cl

as

mo,

cl

as

mo,

cl

as

as

as

as

as as

as

as

mo,

cl

mo,

cl

mo,

cl

Assessment of localized weather data based on available data from other relevant sites. Consists of several ambient parameters.

Demand response triggers received with

timestamps

Cl

AN

cl cl cl cl

cl

cl

cl

cl cl

cl

cl

cl

cl

cl

Assumed – all sites are equipped with smart meters or equivalent devices.

99



Recipient of



Islanded Microgrids


Comments


Type

of d

ata:

Char

acte

ristic

of d

ata:

Exis

tenc

e/us

age

of re

leva

nt

stan

dard

s:

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a

win

d fa

rm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of

DER

s as

a d

istri

butio

n-co

nnec

ted

pow

er p

lant

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, ap

artm

ent,

com

mer

cial

, in

dust

rial)

Pre-

plan

ned

mic

rogr

id w

ith

com

bine

d m

anag

emen

t and

t

Au

tono

mou

s de

cent

raliz

ed

cont

rol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of A

C a

nd D

C

Auto

nom

ous

no m

onito

ring,

no

cont

rol

Auto

nom

ous

no m

onito

ring,

br

oadc

ast i

nstru

ctio

ns a

nd

dli

d l

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g, n

o t

l W

ith n

ear-r

eal-t

ime

mon

itorin

g,

dire

ct c

omm

unic

atio

ns a

nd

Commands issued for Demand

Response (to thermostats,

appliances, DER, Storage)

Cl

HAN

, AN

cl cl cl cl

cl

cl

cl

cl cl

cl

cl

cl

cl

cl

Instantaneous voltages cl

vario

us

AN

as

mo,

cl

md

mo,

cl

as

mo,

cl

as

as

md as

as

mo,

md

mo,

md

mo,

cl Selected critical

voltages from DER-Load aggregations represented in the EMS of aggregations.

Instantaneous frequency from

dedicated meters in autonomous mode of

microgrid cl

vario

us

AN

as

mo,

cl

md

mo,

cl

as

mo,

cl

as

as

md as

as

mo,

md

mo,

md

mo,

cl

Last Gasp/AC Out (Outage detection) cl

vario

us

AN

mo,

as

mo,

cl

as

mo,

cl

mo,

as

mo,

cl

mo,

as

mo,

as

as

mo,

as

mo,

as

mo,

as

mo,

as

mo,

cl Selected AC Out signals

from DER-Load aggregations represented in the EMS of aggregations.

The AMI/DER/ DR Data

Management Systems

Smart Meter or

equivalent device

Real-time prices, their timeframes, and

allocation

us

ct, a

l, ar

AN, C

M

us

us

us

us

us

us

us

us

us

us

us

us

us

us

us

us

us

us

us

It can be near-real-time data and/or a predictive schedule. For a VPP, it can be one common price, or different allocated prices.

Demand response triggers, amount, location, duration,

and kW-kvar composition

cc, u

m

al, a

r

AN, C

M

us, a

g or

al,

us

us

us

us, a

g or

al,

us

us, a

g or

al,

us, a

g or

al,

us

us, a

g or

al,

us, a

g or

al,

us, a

g or

al,

us us

us

us

us

us

Demand response can be executed by load reduction and/or by DG/ES control (e.g., the kW can be met by load and the kvar by DER).

Requests for collected data cc

ar

AN,

CM

Applicable to all The contents of the requests may be different for different categories in accordance with the relevance and availability of data. Some of the data

may be indirectly related to DERs

The request may define the contents of data and the length of history.

Requests for instantaneous

and/or near-real-time data

cc

ar

AN,

CM

Applicable to all The contents of the requests may be different for different categories in accordance with the relevance and availability of data. Some of the data

may be indirectly related to DERs

100



Recipient of



Islanded Microgrids


Comments


Type

of d

ata:

Char

acte

ristic

of d

ata:

Exis

tenc

e/us

age

of re

leva

nt

stan

dard

s:

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a

win

d fa

rm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of

DER

s as

a d

istri

butio

n-co

nnec

ted

pow

er p

lant

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, ap

artm

ent,

com

mer

cial

, in

dust

rial)

Pre-

plan

ned

mic

rogr

id w

ith

com

bine

d m

anag

emen

t and

t

Au

tono

mou

s de

cent

raliz

ed

cont

rol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of A

C a

nd D

C

Auto

nom

ous

no m

onito

ring,

no

cont

rol

Auto

nom

ous

no m

onito

ring,

br

oadc

ast i

nstru

ctio

ns a

nd

dli

d l

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g, n

o t

l W

ith n

ear-r

eal-t

ime

mon

itorin

g,

dire

ct c

omm

unic

atio

ns a

nd

Additional information:

requests/commands for DER control

cc,

um

ar

AN,

CM

Applicable to all DERs and microgrids capable of corresponding controls May include: modes and settings of volt/var control, frequency control, protection settings (RT), RAS settings, DG power curtailment, etc.

microgrid controller/

EMS in PCC

AMI/DER/ DR Data

Management Systems of

the DMS

Aggregated for microgrid data

Net, load and generation - kW and

kvar

mo

ag

61, C

M

ag, a

s

ag,a

s

as, c

l

as, c

l

as, c

l

as, c

l

cl

cl

cl

For autonomous microgrids, other non-standard communication means can be used, e.g., e-mails.

Net, consumption and generation kWh

mo

ag

61, C

M

ag, a

s

ag,a

s

as, c

l

as, c

l

as, c

l

as, c

l

cl

cl

cl


Net, load and generation load

profiles

cl

ag, a

r

61, C

M

um

um

as, c

l

as, c

l

as, c

l

as, c

l

cl

cl

cl


Interval average voltages at the PCC

mo al

61, C

M

as

as

as, c

l

as, c

l

as, c

l

as, c

l

cl

cl

cl


101



Recipient of



Islanded Microgrids


Comments


Type

of d

ata:

Char

acte

ristic

of d

ata:

Exis

tenc

e/us

age

of re

leva

nt

stan

dard

s:

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a

win

d fa

rm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of

DER

s as

a d

istri

butio

n-co

nnec

ted

pow

er p

lant

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, ap

artm

ent,

com

mer

cial

, in

dust

rial)

Pre-

plan

ned

mic

rogr

id w

ith

com

bine

d m

anag

emen

t and

t

Au

tono

mou

s de

cent

raliz

ed

cont

rol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of A

C a

nd D

C

Auto

nom

ous

no m

onito

ring,

no

cont

rol

Auto

nom

ous

no m

onito

ring,

br

oadc

ast i

nstru

ctio

ns a

nd

dli

d l

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g, n

o t

l W

ith n

ear-r

eal-t

ime

mon

itorin

g,

dire

ct c

omm

unic

atio

ns a

nd

Weather data in the microgrid area

mo

al a

r

CM

as

as

as, c

l

as, c

l

as, c

l

as, c

l

cl

cl

cl


Demand response commands/requests

received with timestamps

cl

ar

CM

cl

Cl,

um

as, c

l

as, c

l

as, c

l

as, c

l

cl

cl

cl

The requests for DR may include the amount of kW and kvar reduction and the timing. For autonomous microgrids, other non-standard communication means can be used, e.g., e-mails.

Commands issued for Demand

Response (to customers’ smart

meters, thermostats, appliances, DER,

storage)

cl

ar

CM

as, a

g

as a

g, u

m

as, c

l

as, c

l

as, c

l

as, c

l

cl

cl

cl


Protection settings and settings for frequency and

voltage control for connected and for

autonomous modes of operations

mo,

cl

ar

61, C

M

ar

ar cl

cl

cl

cl

mo

mo

mo


Operational limits, e.g., dynamic limits of interval average

voltages at the PCC

mo,

cl

us

61, C

M

us

us

us

cl

cl

cl

cl

mo

mo

mo

In addition to contract voltage limits at the PCC, different dynamic limits can be used for mutual benefits of EPS and microgrid.

102



Recipient of



Islanded Microgrids


Comments


Type

of d

ata:

Char

acte

ristic

of d

ata:

Exis

tenc

e/us

age

of re

leva

nt

stan

dard

s:

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a

win

d fa

rm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of

DER

s as

a d

istri

butio

n-co

nnec

ted

pow

er p

lant

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, ap

artm

ent,

com

mer

cial

, in

dust

rial)

Pre-

plan

ned

mic

rogr

id w

ith

com

bine

d m

anag

emen

t and

t

Au

tono

mou

s de

cent

raliz

ed

cont

rol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of A

C a

nd D

C

Auto

nom

ous

no m

onito

ring,

no

cont

rol

Auto

nom

ous

no m

onito

ring,

br

oadc

ast i

nstru

ctio

ns a

nd

dli

d l

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g, n

o t

l W

ith n

ear-r

eal-t

ime

mon

itorin

g,

dire

ct c

omm

unic

atio

ns a

nd

Cost functions for services

um

ct, a

r

CM

ar

ar

ar

ar

ar

ar

ar

ar

ar

ar


Other data needed for current and

predictive model of microgrid operations

Microgrid inter-

connection controller (EMS) in

PCC

AMI/DER/ DR Data

Management Systems of

the DMS

Lowest /highest instantaneous

voltages from PCC

mo,

as

ar

61, C

M

mo

mo as

as

as

as

mo

mo

mo

Instantaneous frequency

mo,

as

61, C

M

mo

mo as

as

as

as

mo

mo

mo

Last Gasp/AC Out from selected smart

meters mo 61

mo

mo

mo

mo

mo

Additional data: Aggregated natural load-to-voltage (in

PCC) dependencies

as

ar

CM

mo

mo

as

as

as

as

mo

mo

mo

Including normal and emergency ranges.

103



Recipient of



Islanded Microgrids


Comments


Type

of d

ata:

Char

acte

ristic

of d

ata:

Exis

tenc

e/us

age

of re

leva

nt

stan

dard

s:

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a

win

d fa

rm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of

DER

s as

a d

istri

butio

n-co

nnec

ted

pow

er p

lant

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, ap

artm

ent,

com

mer

cial

, in

dust

rial)

Pre-

plan

ned

mic

rogr

id w

ith

com

bine

d m

anag

emen

t and

t

Au

tono

mou

s de

cent

raliz

ed

cont

rol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of A

C a

nd D

C

Auto

nom

ous

no m

onito

ring,

no

cont

rol

Auto

nom

ous

no m

onito

ring,

br

oadc

ast i

nstru

ctio

ns a

nd

dli

d l

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g, n

o t

l W

ith n

ear-r

eal-t

ime

mon

itorin

g,

dire

ct c

omm

unic

atio

ns a

nd

Additional data: Aggregated DER

generation-to-voltage(in PCC) dependencies

as

ar

CM

mo

mo

as

as

as

as

mo

mo

mo


Additional data: Aggregated natural load-to-frequency

dependencies

as

ar

CM

mo

mo

as

as

as

as

mo

mo

mo



generation-to-frequency

dependencies

as

ar

CM

mo

mo

as

as

as

as

mo

mo

mo



capability curves as Functions of kW,

kvar and Volt in PCC

as

ar

CM

mo

mo as

as

as

as

mo

mo

mo

Including normal and emergency ranges

Additional data: Current and look-

ahead dispatchable load data

as

ar

CM

mo

mo as

as

as

as

mo

mo

mo


Additional data: Data on overlaps of load management

means

as

ar

CM

as

as

as

as

as

as

as

as

as

as


104



Recipient of



Islanded Microgrids


Comments


Type

of d

ata:

Char

acte

ristic

of d

ata:

Exis

tenc

e/us

age

of re

leva

nt

stan

dard

s:

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a

win

d fa

rm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of

DER

s as

a d

istri

butio

n-co

nnec

ted

pow

er p

lant

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, ap

artm

ent,

com

mer

cial

, in

dust

rial)

Pre-

plan

ned

mic

rogr

id w

ith

com

bine

d m

anag

emen

t and

t

Au

tono

mou

s de

cent

raliz

ed

cont

rol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of A

C a

nd D

C

Auto

nom

ous

no m

onito

ring,

no

cont

rol

Auto

nom

ous

no m

onito

ring,

br

oadc

ast i

nstru

ctio

ns a

nd

dli

d l

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g, n

o t

l W

ith n

ear-r

eal-t

ime

mon

itorin

g,

dire

ct c

omm

unic

atio

ns a

nd

Additional data: Impacts of ambient conditions on net load, dispatchable

load, etc.

as

ar

CM

as

as

as

as

as

as

as

as

as

as

AMI/DER/ DR Data

Management Systems

Microgrid inter-

connection controller in

PCC

Real-time prices

Demand response triggers, amount, location, duration,

and kW-kvar composition

cc, u

m

al, a

r

CM

us, a

g

us, a

g

us us

us

us

us

us

Demand response can be executed by load reduction and/or by DG/ES control (e.g., the kW can be met by load and the kvar by DER). For autonomous microgrids, other non-standard communication means can be used, e.g., e-mails.

Disconnection command for

intentional islanding

cc 61 For autonomous microgrids, other non-standard communication means can be used, e.g., e-mails.

Desired net kW and kvar schedules

cc

ar

CM

ar

ar

ar

ar

ar

ar

ar

ar

ar

ar

May imply the use of demand response, volt/var control, generation curtailments, etc. For autonomous microgrids, other non-standard communication means can be used, e.g., e-mails.

Desired volt/var modes of operations

and setpoints cc

ar

CM

ar

ar

ar

ar

ar

ar

ar

ar

ar

ar


Data requests

cc

ar

CM

The requests can be for collected data and/or for near-real time data.

105



Recipient of



Islanded Microgrids


Comments


Type

of d

ata:

Char

acte

ristic

of d

ata:

Exis

tenc

e/us

age

of re

leva

nt

stan

dard

s:

With

in v

irtua

l pow

er p

lant

With

in a

sub

stat

ion

With

in a

resi

denc

e

With

in a

real

pow

er p

lant

like

a

win

d fa

rm

With

in a

milit

ary

envi

ronm

ent

With

in a

dis

tribu

tion

feed

er a

s a

stan

d-al

one

DER

or g

roup

of

DER

s as

a d

istri

butio

n-co

nnec

ted

pow

er p

lant

With

in a

com

mun

ity

With

in a

cam

pus

envi

ronm

ent

With

in a

bui

ldin

g (o

ffice

, ap

artm

ent,

com

mer

cial

, in

dust

rial)

Pre-

plan

ned

mic

rogr

id w

ith

com

bine

d m

anag

emen

t and

t

Au

tono

mou

s de

cent

raliz

ed

cont

rol

As b

acku

p fo

r any

con

figur

atio

n

AC v

s. D

C m

icro

grid

s, in

clud

ing

com

bina

tions

of A

C a

nd D

C

Auto

nom

ous

no m

onito

ring,

no

cont

rol

Auto

nom

ous

no m

onito

ring,

br

oadc

ast i

nstru

ctio

ns a

nd

dli

d l

Auto

nom

ous

no m

onito

ring,

with

de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g an

d de

cent

raliz

ed c

ontro

l

Auto

nom

ous

with

mon

itorin

g, n

o t

l W

ith n

ear-r

eal-t

ime

mon

itorin

g,

dire

ct c

omm

unic

atio

ns a

nd

Additional data: Requests for amount

and settings of Remedial Action Schemes (RAS) cc

ar

CM

ar

ar

ar

ar

ar

ar

ar

ar

ar

ar

Includes UFLS and/or UVLS, or other LS RAS grouping and settings for the connected mode. For autonomous microgrids, other non-standard communication means can be used, e.g., e-mails.

Additional interfaces:

VPP Management

system

Distribution Operator/

DMS

Data on Technical VPP alternative

um

ct, a

l

CM

ar

The initial TVPP may not meet the Local EPS requirements (limits). It needs approval of the area EPS.

Distribution Operator/

DMS

VPP Managemen

t system

Acceptance of Technical VPP

alternative

um

ct, a

l

CM

ar

The area EPS may change the setup of the TVPP according to the EPS requirements.

106


Codes: Characteristic of data: ns – not provided by object model standards md – modeling data required ag – aggregated data al - disaggregated or allocated data ct - contractual or market data tb - TBLM data ar –array or table Type of data: cc - control command/request us - updated settings mo - monitored cl – collected measurements as - assessment/analysis um - needs updates of object model Existence/usage of relevant standards: 61 - 61850 CM – CIM DN - DNP3 AN - ANSI C12.x After the types and characteristics of data for each DER system categories are defined, the data models can be suggested, if needed, and the gaps in the standards can be determined. For some of the data models, the standards may exist; for some, they do not exist; for others, they may exist in principal, but may need updates; and for some, no standardization is needed. An illustration of a high-level gap analysis of the standards for a portion of the volt-var use case, mostly addressing the communications between architectural levels 1 -2 and level 4, is presented in Appendix D.

107