DNP Application Note AN2018-001 Version 2018-08-22 DNP3 Profile for Communications with Distributed Energy Resources (Ders)

DNP Application Note AN2018-001 Version 2018-08-22 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

1 Introduction This document describes a standard data point configuration, set of protocol services and settings – also known as a profile – for communicating with Distributed Energy Resources (DERs) using DNP3. The IEEE Std. 2030-2011 defines a DER as a “source of electric power that is not directly connected to a bulk power transmission system. DERs include both generators and energy storage technologies.” The purpose of defining this profile is to make it easier to interconnect the DNP3 masters and outstations that are used to control such systems. The definition of DER used in this document is quite broad and may, for instance, include electric vehicles or microgrids. If the outstation is capable of implementing the functions and modes described here, it can likely be considered a DER. Please refer to section 2.1 of this document for more details on what is considered a DER for the purpose of this profile. This document is an application note, meaning it does not specify any changes to the DNP3 standard at all: it merely describes how to use DNP3 for a particular purpose. It is, however, intended to be an interoperability standard for those wishing to build and specify DER systems.

1.1 Sources and References Although this document describes a DNP3 profile, it is designed based on the structured data models of the International Electrotechnical Commission (IEC) 61850 protocol standards family. In particular, it is based on those data models that are specific to DERs. The intent is that a system implementing this DNP3 application note can be easily integrated with an IEC 61850 network by means of a gateway, while remaining conformant with DNP3 best practices. This application note supersedes application note AN2013-001 DNP3 Profile for Advanced Photovoltaic Generation and Storage which in turn superseded AN2011-001 DNP3 Profile for Basic Photovoltaic Generation and Storage. The point numbers, procedures and definitions specified in this application note are not backward-compatible with those earlier documents because the scope and flexibility of the profile have been significantly increased.

NOTE: As an aid to those readers who may be familiar with the earlier versions of this application note, some section names have the designation NEW appended to them, representing functionality that was not provided in the earlier versions.

With these goals in mind, the design of this profile is based on the following documents: • IEC 61850-7-420 Ed. 2.0 (in development) Communication networks and systems for power utility automation - Part 7-420: Basic communication structure - Distributed energy resources

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logical nodes. This document is the IEC specification for standard data models to be used for DERs. The latest version of this standard incorporates models from the technical report IEC 61850-90-7 Ed. 1.0: IEC 61850 object models for inverters in distributed energy resources (DER) systems. The IEC process used by the IEC 61850 working group is to produce technical reports to introduce new concepts, have them in use for a period of time and then incorporate them into an official international standard once proven. • Common Functions for Smart Inverters Version 4 (EPRI reference 3002008217). This document was produced as a result of the work of the Photovoltaic Inverter Data Identification Focus Group (DIFG), organized by the Electric Power Research Institute (EPRI). The members of this group include photovoltaic inverter and storage manufacturers, utilities, research institutions and integrators. The document specifies a common set of application functions required for communicating with a DER system controlled by a “smart” inverter. • IEEE Std. 1815.1-2015: Standard for exchanging information between networks implementing IEC 61850 and IEEE 1815 (DNP3). This is a specification for mapping data between IEC 61850 and DNP3 networks and for configuring a gateway between such networks. This standard was developed through the assistance of the National Institute of Standards and Technology (NIST) and the Smart Grid Interoperability Panel (SGIP) under the label Priority Action Plan Twelve (PAP12). • MESA-ESS Specification from the MESA Standards Alliance. This specification defines the communication requirements for utility-scale energy storage systems (ESS). It was developed in parallel with the development of this application note and describes the subset of the DNP3 profile that will be used by MESA members. To summarize, this document describes a DNP3 profile that implements the DER functions specified by the EPRI Common Functions for Smart Inverters document and that can be mapped to an IEC 61850-7- 420 and IEC 61850-90-7 object model according to the guidelines specified in IEEE Std. 1815.1. It was developed in parallel with the MESA-ESS Specification and describes a superset of the capabilities described in that document. Naturally, complying with specifications from multiple groups with differing mandates in this way requires compromises. Where such compromises are required, the design attempts to follow DNP3 principles of simplicity, reliability, and conciseness.

1.2 DNP3 Level of the Profile The outstation described in this profile shall be a DNP3 Level 2 (DNP3-L2) implementation or higher. Implementors are free to add additional features beyond DNP3-L2 by agreement between the providers of the master and outstation. Previous versions of this profile described a DNP3 Level 3 (DNP3-L3) device with additional data objects developed specifically for the use of this profile. However, feedback from industry stakeholders indicated that compatibility with DNP3-L2 masters is a requirement for this application. Therefore, only DNP3-L2 is required, and workarounds have been found for some of the other capabilities, such as starting schedules at a specific time. If an outstation supports features that are not available in DNP3-L2, it must be possible to disable them for compatibility with DNP3-L2 masters.

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Contents 1 Introduction ...... 1 1.1 Sources and References ...... 1 1.2 DNP3 Level of the Profile ...... 2 2 Details ...... 9 2.1 Overview of the Profile ...... 9 2.1.1 Assumptions in this Profile ...... 10 2.1.2 High-Level Data Model ...... 13 2.2 Points List ...... 17 2.2.1 Point Blocks ...... 17 2.2.2 Numbering Points ...... 20 2.2.3 Event Classes ...... 22 2.2.4 IEC 61850 Mapping ...... 22 2.2.5 Binary Inputs...... 23 2.2.6 Binary Outputs ...... 53 2.2.7 Counters ...... 62 2.2.8 Analog Inputs ...... 68 2.2.9 Analog Outputs ...... 129 2.2.10 Device Attribute Objects (optional) ...... 172 2.3 Overview of DER Modes and Functions ...... 178 2.3.1 Support for Modes and Functions – NEW ...... 178 2.3.2 Mode Enabling Timing Parameters ...... 179 2.3.3 Multiplexed Generic Curves and Schedules ...... 179 2.3.4 Limiting Response: Ramp Rates, Ramp Times and Time Constants - NEW ...... 181 2.3.5 Use of Broadcasting ...... 184 2.4 Basic DER Functions ...... 185 2.4.1 Monitoring ...... 185 2.4.2 Use of Signal Meters ...... 186 2.4.3 Alarm Grouping and Reporting - NEW ...... 186 2.4.4 Connect and Disconnect Functions ...... 187 2.4.5 Cease to Energize and Return to Service Functions – NEW ...... 187 2.4.6 Operational States ...... 189 2.4.7 Time Synchronization Function ...... 191 2.4.8 Event/History Logging Function ...... 191 2.5 Emergency Modes ...... 191

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2.5.1 Low/High Voltage Ride-Through Mode ...... 192 2.5.2 Low/High Frequency Ride-Through Mode – NEW ...... 195 2.5.3 Frequency-Watt Mode – NEW ...... 197 2.5.4 Dynamic Reactive Current Support Mode ...... 200 2.5.5 Dynamic Volt-Watt Mode ...... 204 2.6 Active Power Modes ...... 207 2.6.1 Active Power Limit Mode ...... 207 2.6.2 Charge/Discharge Storage Mode ...... 208 2.6.3 Coordinated Charge/Discharge Management Mode – NEW ...... 210 2.6.4 Active Power Response Modes ...... 211 2.6.5 Automatic Generation Control Mode – NEW ...... 214 2.6.6 Active Power Smoothing ...... 215 2.6.7 Volt-Watt Mode ...... 218 2.6.8 Frequency-Watt Curve Mode ...... 221 2.7 Reactive Power Modes ...... 224 2.7.1 Constant VArs Mode – NEW ...... 224 2.7.2 Fixed Power Factor Mode ...... 225 2.7.3 Volt-VAr Control Mode ...... 227 2.7.4 Watt-VAr Power Mode – NEW ...... 231 2.7.5 Power Factor Correction Mode – NEW ...... 232 2.8 Pricing Signal Mode ...... 233 2.9 Scheduling of Modes ...... 234 2.10 Interaction Between Settings...... 236 2.10.1 Local State ...... 236 2.10.2 Lockout State ...... 237 2.10.3 Priority of Last Command ...... 237 2.10.4 Compatibility and Priority of Modes and Functions ...... 237 2.11 Grid Configurations and Islanding ...... 240 2.11.1 Possible Grid Configurations ...... 240 2.11.2 Settings Groups ...... 240 2.11.3 Settings Group Control Parameters ...... 241 2.11.4 Sensing the Grid Configuration ...... 242 2.11.5 Modes of Operation When Islanded ...... 243 2.12 Implementation Table ...... 244 2.13 Mapping to IEEE Std 1547-2018 ...... 247 3 Conclusions ...... 249 4 Submitted By ...... 249 Page 4 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

5 Disclaimer...... 249

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Table of Figures FIGURE 1 – ASSUMED DER STRUCTURE ...... 12 FIGURE 2 – SIMPLE DER ...... 12 FIGURE 3 - EXAMPLE OF AN IEC 61850 NAME ...... 13 FIGURE 4 – ORGANIZATION OF THE POINTS LIST ...... 19 FIGURE 5 – PLACEMENT OF VENDOR-SPECIFIC POINTS ...... 20 FIGURE 6 – GENERIC CURVE CONCEPT ...... 180 FIGURE 7 – EXAMPLE TIME DOMAIN RESPONSE FROM FIRST-ORDER LOW-PASS FILTER ...... 184 FIGURE 8 - IEC 61850-7-420 DER STATE DIAGRAM (DRAFT) ...... 190 FIGURE 9 – EXAMPLE OF VOLTAGE RIDE-THROUGH REQUIREMENTS ...... 193 FIGURE 10 – RIDE-THROUGH CURVES AND AREAS BETWEEN CURVES ...... 194 FIGURE 11 – FREQUENCY-WATT MODE (STARTED WHEN GENERATING) ...... 197 FIGURE 12 – FREQUENCY-WATT MODE (STARTED WHEN CHARGING) ...... 199 FIGURE 13 – DELTA VOLTAGE CALCULATION ...... 200 FIGURE 14 – DYNAMIC CURRENT SUPPORT FUNCTION ...... 201 FIGURE 15 – ALTERNATE DYNAMIC CURRENT GRADIENT MODE ...... 202 FIGURE 16 – EVENT-BASED DYNAMIC CURRENT SUPPORT ...... 202 FIGURE 17 – SETTINGS TO DEFINE A DYNAMIC REACTIVE CURRENT BLOCKING ZONE ...... 203 FIGURE 18 – DELTA VOLTAGE CALCULATION FOR DYNAMIC VOLT-WATT MODE ...... 205 FIGURE 19 – DYNAMIC VOLT-WATT MODE ...... 206 FIGURE 20 – RELATIONSHIPS BETWEEN STORAGE PARAMETERS ...... 209 FIGURE 21 – COORDINATED CHARGE/DISCHARGE MODE ...... 210 FIGURE 22 – PEAK POWER LIMITING FUNCTION ...... 212 FIGURE 23 – LOAD FOLLOWING FUNCTION ARRANGEMENT AND WAVEFORM ...... 213 FIGURE 24 – GENERATION FOLLOWING FUNCTION ARRANGEMENT AND WAVEFORM ...... 214 FIGURE 25 – POSSIBLE MEASUREMENT POINTS ...... 216 FIGURE 26 – DELTA WATTAGE CALCULATION ...... 216 FIGURE 27 – ACTIVE POWER SMOOTHING MODE ...... 217 FIGURE 28 – EXAMPLE VOLT-WATT CURVE ...... 219 FIGURE 29 – BASIC FREQUENCY-WATT CURVE ...... 221 FIGURE 30 – FREQUENCY-WATT CURVE WITH HYSTERESIS ...... 222 FIGURE 31 – POWER FACTOR SIGN CONVENTIONS ...... 226 FIGURE 32 – VOLT/VAR CURVE WITH HYSTERESIS ...... 228 FIGURE 33 – VOLT/VAR CURVE WITHOUT HYSTERESIS ...... 229 FIGURE 34 – POWER FACTOR CORRECTION MODE EXAMPLE ...... 233 FIGURE 35 – SETTINGS GROUPS ...... 241 FIGURE 36 – PARAMETERS FOR CONTROLLING SETTINGS GROUPS ...... 242 FIGURE 37 – POSSIBLE INPUTS DETERMINING ACTIVE SETTINGS GROUP ...... 242 FIGURE 38 – GRID CONFIGURATION AND ISLANDING CONTEXT ...... 243

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Table of Tables TABLE 1 – IEC 61850 CONNECTION POINT TYPES (DER METER TYPES) ...... 11 TABLE 2 – IEC 61850 LOGICAL NODES IN THIS PROFILE ...... 15 TABLE 3 – CATEGORIES OF POINTS ...... 18 TABLE 4 – PERMITTED IMPLEMENTATION LEVELS ...... 19 TABLE 5 – ABBREVIATIONS AND CONSTANTS USED IN NUMBERING THE POINTS LISTS ...... 21 TABLE 6 – DEFAULT EVENT CLASSES IN THIS PROFILE ...... 22 TABLE 7 – MEANINGS OF THE IEC 61850 COLUMNS ...... 22 TABLE 8 – IEC 61850 COMMON DATA CLASSES REFERENCED BY THIS PROFILE ...... 22 TABLE 9 – BINARY INPUT POINTS LIST ...... 24 TABLE 10 – BINARY INPUT PROTOCOL OPTIONS ...... 52 TABLE 11 – CONTROL OPERATIONS SUPPORTED ...... 53 TABLE 12 – BINARY OUTPUT POINTS LIST ...... 54 TABLE 13 – BINARY OUTPUT PROTOCOL OPTIONS ...... 59 TABLE 14 – COUNTER POINTS LIST ...... 64 TABLE 15 – COUNTER PROTOCOL OPTIONS ...... 65 TABLE 16 – ANALOG INPUT POINTS LIST ...... 69 TABLE 17 – ANALOG INPUT PROTOCOL OPTIONS...... 125 TABLE 18 – REQUIRED CONTROL OPERATIONS FOR ANALOG OUTPUTS ...... 130 TABLE 19 - ANALOG OUTPUT POINTS LIST ...... 131 TABLE 20 – SCALING FOR GENERIC CURVE INDEPENDENT VARIABLES (X-VALUE) ...... 168 TABLE 21 – SCALING FOR GENERIC CURVE DEPENDENT VARIABLES (Y-VALUE) ...... 169 TABLE 22 – ANALOG OUTPUT PROTOCOL OPTIONS ...... 170 TABLE 23 – STANDARD DEVICE ATTRIBUTE OBJECTS (POINT NUMBER 0) ...... 173 TABLE 24 – PV/STORAGE DEVICE ATTRIBUTE OBJECTS (POINT NUMBER 2) ...... 176 TABLE 25 – VALUES FOR TIMING PARAMETERS ...... 179 TABLE 26 – RESPONSE LIMITING PARAMETERS ...... 182 TABLE 27 – USE OF TIME CONSTANTS AND RAMP RATES ...... 183 TABLE 28 – STEPS TO READ AND REPORT STATUS USING THE DNP3 DER PROFILE ...... 185 TABLE 29 – STEPS TO PERFORM A CONNECT/DISCONNECT DER ...... 187 TABLE 30 – STEPS TO CAUSE THE DER TO CEASE TO ENERGIZE AND RETURN TO SERVICE ...... 188 TABLE 31 – OPERATIONAL STATES AND BINARY INPUTS ...... 189 TABLE 32 – LOW/HIGH VOLTAGE RIDE-THROUGH CURVE MODE TYPES ...... 192 TABLE 33 – STEPS TO DEFINE THE LVRT AND HVRT MODES USING THE DNP3 DER PROFILE ...... 195 TABLE 34 – LOW/HIGH FREQUENCY RIDE-THROUGH CURVE MODE TYPES ...... 196 TABLE 35 – STEPS TO DEFINE THE LFRT AND HFRT MODES USING THE DNP3 DER PROFILE ...... 196 TABLE 36 – STEPS TO ENABLE FREQUENCY-WATT MODE USING THE DNP3 DER PROFILE ...... 199 TABLE 37 – STEPS TO ENABLE DYNAMIC REACTIVE CURRENT MODE ...... 204 TABLE 38 – STEPS TO ENABLE DYNAMIC VOLT-WATT MODE USING THE DNP3 DER PROFILE ...... 207 TABLE 39 – STEPS TO ENABLE ACTIVE POWER LIMIT MODE USING THE DNP3 DER PROFILE ...... 208 TABLE 40 – USE OF RAMP RATES OR TIME CONSTANTS TO LIMIT CHARGE/DISCHARGE MODE ...... 209 TABLE 41 – STEPS TO CHARGE OR DISCHARGE STORAGE USING THE DNP3 DER PROFILE ...... 210 TABLE 42 – STEPS TO ENABLE COORDINATED CHARGE/DISCHARGE MODE ...... 211 TABLE 43 – STEPS TO ENABLE ACTIVE RESPONSE MODES USING THE DNP3 DER PROFILE ...... 212 TABLE 44 – USE OF RAMP RATES OR TIME CONSTANTS TO CONSTRAIN AGC MODE ...... 215 TABLE 45 – STEPS TO PERFORM AUTOMATIC GENERATION CONTROL (AGC) USING THE DNP3 DER PROFILE ...... 215 TABLE 46 – STEPS TO ENABLE ACTIVE POWER SMOOTHING USING THE DNP3 DER PROFILE ...... 217 TABLE 47 – STEPS TO ENABLE A VOLT-WATT CURVE USING THE DNP3 DER PROFILE ...... 220 TABLE 48 – STEPS TO ENABLE A FREQUENCY-WATT CURVE USING THE DNP3 DER PROFILE ...... 223 TABLE 49 – CHOICES FOR THE MEANING OF THE CONSTANT VARS REACTIVE POWER TARGET ...... 224 TABLE 50 – STEPS TO SET CONSTANT VAR OUTPUT USING THE DNP3 DER PROFILE ...... 225 TABLE 51 – PARAMETERS AND BEHAVIOR WHEN SETTING A FIXED POWER FACTOR ...... 226 TABLE 52 – STEPS TO SET A FIXED POWER FACTOR USING THE DNP3 DER PROFILE ...... 227

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TABLE 53 – CHOICE OF REFERENCE REACTIVE POWER ...... 228 TABLE 54 – STEPS TO CHANGE AND SELECT A VOLT/VAR CURVE ...... 230 TABLE 55 - STEPS TO ENABLE WATT-VAR POWER MODE USING THE DNP3 DER PROFILE ...... 232 TABLE 56 – STEPS TO ENABLE POWER FACTOR CORRECTION MODE USING THE DNP3 DER PROFILE ...... 233 TABLE 57 – STEPS TO SIGNAL A PRICE CHANGE USING THE DNP3 DER PROFILE ...... 234 TABLE 58 – SCHEDULE VALUE INTERPRETATION BASED ON SCHEDULE TYPE ...... 235 TABLE 59 – STEPS TO CREATE AND ENABLE SCHEDULES ...... 236 TABLE 60 – SETTINGS AFFECTING PRIORITY OF DER BEHAVIOR ...... 238 TABLE 61 – COMPATIBILITY OF MODES ...... 239 TABLE 62 – DNP3 IMPLEMENTATION TABLE FOR THE DNP3 DER PROFILE...... 244 TABLE 63 - MAPPING OF IEC STD 1547 TO THE DNP3 DER PROFILE ...... 247

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2 Details This section describes the profile in detail. The profile consists of: • An overview describing the assumed structure of DERs and the high-level organization of the IEC 61850-7-420 data model used. • The list of DNP3 data points that shall be provided by devices implementing this application note and the IEC 61850 name that corresponds to each point.

NOTE: Unlike the previous application notes AN2011-001 and AN2013-001, the DNP3 points list described in this application note is not identical for all DERs. The configuration of any DER may include different numbers of generators, loads, inverters, storage units and meters, all of which will affect the number of data points provided by the outstation. However, the intent is that any device that implements this application note for a system having the same configuration shall use the same point indices and data objects, and it will be deterministic and unambiguous what those points are. Data specific to a particular supplier can be added using indices higher than those described here.

• The list of DNP3 services (i.e. function codes, objects and point indices) that shall be used to implement each of the functions specified by the source documents. • A protocol implementation conformance statement (PICS) form showing which functions are required and which are optional. The reader of this profile is expected to be familiar with DNP3 and understand DERs. It is useful, but not required, for the reader to be familiar with IEC 61850. Readers who are not familiar with DNP3 or IEC 61850 but are (for instance) reading this profile to become familiar with DER functionality should note that this profile follows a terminology convention common to all Supervisory Control and Data Acquisition (SCADA) systems : • A data point is the smallest unit of data transferred by the protocol. • An input point is any data transmitted toward the master; in this case from the DER to the power utility or some other entity controlling the DER. • An output point is any data transmitted toward the outstation; in this case from the power utility or other controlling entity to the DER. These terms apply only to the data communications and are distinct from the power input to the DER and output from the DER.

2.1 Overview of the Profile As described in the reference documents, DERs may be deployed in a variety of configurations. There are many different possible combinations and topologies of panels, inverters, switches, storage units, controllers and other equipment. Therefore, to simplify this profile and make it easier to implement, a number of assumptions have been made. This section lists those assumptions and graphically presents the assumed structure of the corresponding photovoltaic system. This section also describes the structure of the IEC 61850 data model that this profile is based on.

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2.1.1 Assumptions in this Profile This profile makes the following assumptions about the structure of the DER, as illustrated in Figure 1. Many of these assumptions and terms are derived from those used by the IEEE Std 1547 and the IEC 61850-7-420 standard. 1. Communications is between a DNP3 master and a single outstation. Some DERs include multiple processors and controllers. However, this profile assumes that the DNP3 communications takes place with a single device that acts as a proxy for any others. This device may be an inverter, but it could just as easily be some other device. The DNP3 outstation is labeled “Controller” in the figure. 2. The DER is part of a local electrical power system (EPS). The Local EPS: o Has a single connection to the area EPS, which is typically the power utility distribution network. This is known as the Point of Common Coupling (PCC). o May contain more than one DER, e.g. at different buildings on a campus, together having a single PCC to the power utility. For the purposes of this profile, if a group of equipment has a separate controller acting as a DNP3 outstation that can adjust the input and output of the group, that group is considered a separate DER. o May contain load as well as generation and storage. Load that is located within the local EPS, i.e. is connected to the area EPS via the PCC, is known as local load. 3. The DER consists of the following entities, each of which has its own block of input and output data points defined in this profile: o A Controller or System, as just described. o At least one DER Unit. There may be several DER Units within the DER. A DER Unit consists of: ▪ An Inverter that converts between AC and DC electricity. The assumption in this profile is that this is a “smart” inverter, i.e. capable of data communications and adjusting its operation in response to remote requests. ▪ At least one DC energy source. These sources may be storage devices, generation devices (e.g. photovoltaic panels), or some combination of the two. If the DER Unit contains storage, the outstation may choose to report information associated with the storage using the block of points defined for a Battery. There are no blocks of points defined in this profile that are associated with any other specific type of energy source. o At least one Meter. Meters are categorized in IEC 61850 and in this profile by their location in and around the DER, as illustrated in Figure 1 and listed in Table 1. The number in angle brackets, , is the IEC 61850 enumerated value specifying that type of connection.

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Table 1 – IEC 61850 Connection Point Types (DER Meter Types) Connection Name Details Type

There is only one meter of this type in the DER. This is the System Meter for the DER, and the only metering point that is mandatory in this profile. Some specifications call this location the DER Point of Connection (POC). <1> DER to Local EPS The System Meter measures the input and output of ALL DER Units at the point where they connect to the local EPS. The System Meter points are grouped with the other System points describing the operation of the DER as a whole.

This connection type may represent any meter within the DER that is not the System Meter and does not specifically measure load. In <2> Internal to DER Figure 1 this type of meter is shown measuring groups of DER Units.

Local EPS with Load to <3> Area EPS This type of meter is at the Point of Common Connection (PCC). A different IEC connection point type is assigned depending on Local EPS without Load <4> whether the local EPS contains load. to Area EPS

<5> Load to Local EPS This type of meter measures only the local load.

External to DER beyond <6> This type of meter is sometimes called a Signal Meter. It measures the PCC a point outside the DER such as another DER in the local EPS or another generation source. This type of meter is used as input by External to the DER some DER functions, e.g. load following, generation following, or <7> within the Local EPS peak power limiting.

This type of meter measures loads that are local to the DER itself, <8> Auxilliary Load such as heaters, video cameras, or other security equipment.

Group of DERs to the <9> This type of connection is not illustrated in the figure. Area EPS

o An optional DER Switch, also known as the “Physical Disconnect” switch at the point where the entire DER connects to the local EPS, i.e. at the same point the System Meter measures. Some DERs may not include this switch or may not permit it to be operated remotely. 4. “Islanding” of the DER or local EPS using another PCC Switch is partly out of the scope of this profile. The concept is discussed in section 2.11, but only with regard to the configuration and communications of one particular DER. System-level interactions and algorithms to support multiple devices in an islanded condition are the domain of an island master controller and are out of the scope of this document. 5. Almost all of the DER components discussed here are optional. Figure 1 illustrates a large DER, but a DER can be as simple as that shown in Figure 2.

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PCC External DER Unit 1 Switch Within the Local EPS <7> Local EPS to Inverter 1 Battery 1 Area EPS (PCC) DER Unit 2 <3> or <4> Internal to Transformer 1 DER <2>

Inverter 2 Battery 2

DER Unit 3 Controller DER Switch Inverter 3 Battery 3

DER Unit 4 DER to Local EPS Internal to Transformer 2 (System Meter) DER <2> <1> Inverter 4 Solar PV 1

External DER Unit 5 Beyond the PCC <6>

Internal to Transformer 3 Inverter 5 Battery 4 Description DER <2>

Metering Point AuxIlliary Load <8> Solar PV 2 IEC 61850 Load to LEGEND Connection Local EPS Type <5>

Figure 1 – Assumed DER Structure

No remotely Inverter controllable performs swtiches measurements Local EPS To Area EPS Type <3> or <4>

DER to Local EPS Transformer Inverter Battery (System Meter) (Contains Type <1> Controller)

Local Load (un-metered)

Figure 2 – Simple DER

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2.1.2 High-Level Data Model This section is of interest only to those readers who wish to understand the IEC 61850 data model underlying the points list in section 2.2. Users of DNP3 may be familiar with the concept that the data reported to the master station is just a simplified view, or model, of what is actually happening at the remote site. There may be many complex interactions between devices that are simply summarized for the benefit of the master. The collection of data reported and controlled by the DNP3 outstation is known as its data model. This terminology is not commonly used in the DNP3 documentation, but each DNP3 outstation has a data model nonetheless. In DNP3, the data model is “flat”. Each data point is simply numbered and there is no indication within the protocol itself of how one point relates to another. In IEC 61850 data models, each piece of data has a human-readable text name that uniquely identifies it. IEC 61850 names have a hierarchical structure, similar to a file system, so that each point of data has an implied relationship with the others. IEC 61850 names consist of the hierarchy shown in Figure 3: logical devices which contain logical nodes, which contain data objects, which may contain several layers of data attributes. A logical node is a grouping of data associated with a particular electrical system function. Logical nodes are designated by four-character class names. If there is more than one logical node of the same class (performing the same function but on another part of the system) they are distinguished by one-or-two- character instance numbers. If a device implements a particular electrical system function, it must report and/or control the set of mandatory data objects associated with the corresponding logical node as specified by the IEC 61850-7 set of standards.

Part of name What it means Example of an alternative Logical Device Name Chosen by the utility Feeder3 Logical Node Prefix -- not used in this example -- Logical Node Class Metering Measurement Unit PDIS – Protection, Distance Logical Node Instance Feeder number 3 7 Data Name Phase-to-Ground Voltages PPV – Phase-to-phase volts Data Attribute Name Phase A PhsB – Phase B Neut – Neutral Data Attribute Name Complex value after deadbanding instMag – Instantaneous value Data Attribute Name Magnitude of the complex value ang – angle in degrees Data Attribute Name Floating point value i – integer value

Data Attribute Names – defined in a Common Data Class (CDC)

Bay12Unit2/MMXU3.PhV.phsA.cVal.mag.f

Figure 3 - Example of an IEC 61850 Name

The logical nodes included in this profile are identified in Table 2. Note that logical node names beginning with “D” are considered specific to DERs. The logical nodes fall into the following general categories: • Nodes that model physical equipment such as Fuse (XFUS), Battery (DBAT), Distributed Generator (DGEN), Inverter (DINV), Electrical Connection Point (DECP), and Connect/Disconnect Switch (CSWI). • Nodes that describe the functions or modes of behavior of the DER, such as Fixed Power Factor mode (DFPF), Volt-VAR Control mode (DVVC), Automatic Generation Control (DAGC) or

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Generation-Charging Mode (DWGC), also known as storage charge/discharge. This minimum set of behavior modes and functions has been defined by the EPRI specification Common Functions for Smart Inverters and IEC 61850-7-420, as described in sections 2.3 through 2.7 of this profile. The set points defined in these logical nodes control automatic behavior of the physical equipment. Associated with some of these modes are curve definitions (FMAR), e.g Volt/VAR curves. • Nodes that monitor the status of the system such as Measurements (MMXU), Metering (MMTR), DC Measurements (MMDC), Alarms (CALH). • Nodes that control the system at a higher level, choosing when to act in each mode and what the limits of the system such as: DER Cease to Energize (DCTE). Settings in the Schedule Control logical node select from several possible Schedules (FSCH). Each schedule specifies changes in the operating setpoints of the equipment based on time, temperature, or price. The mandatory data objects and data attributes associated with these logical nodes are defined in the IEC 61850-7-4 and IEC 61850-7-420 standards. They were used to determine the DNP3 points list in section 2.2.

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Table 2 – IEC 61850 Logical Nodes in this Profile Class Description General Category DCTE Cease to Energize (or Initialization) Function Control FSCC Schedule Control Control FSCH Schedule Control CSWI DER Connect/Disconnect Switch Equipment DECP Electrical Connection Point Equipment DGEN Distributed Generator Equipment DINV Inverter Equipment DSTO Storage Equipment SBAT Storage Battery Equipment XFUS Fuse Equipment DAGC Automatic Generation Control Mode Mode DFPF Fixed Power Factor Mode Mode DFWC Frequency-Watt (Curve) Mode Mode DGFL Generation Following Mode Mode DGSM Operational Mode Control Mode DHFT High Frequency Ride-Through Mode DHFW High Frequency-Watt Mode (using Parameters) Mode DHVT High Voltage Ride-Through Mode DLFL Load Following Mode Mode DLFT Low Frequency Ride-Through Mode DLFW Low Frequency-Watt Mode (using Parameters) Mode DLVT Low Voltage Ride-Through Mode DPFC Power Factor Correction Mode Mode DPKP Peak Power Limiting Mode Mode DPRG Pricing Signal (Generation) Mode Mode DRGS Dynamic Reactive Current (Generation) Support Mode DTCD Coordinated Charge-Discharge Mode Mode DVAR Constant VAr Mode Mode DVVC Volt-VAR Control Mode Mode DVWC Volt-Watt (Curve) Mode Mode DVWD Volt-Watt (Dynamic) Mode Mode Watt Generation-Charging Mode Mode DWGC (Charge/Discharge Storage) DWLM Watt (Active Power) Limit Mode Mode DWSM Watt (Active Power) Smoothing Mode Mode DWVR Watt-VAr Mode Mode FMAR Mode Curves and Parameters Mode FWHZ Set Power Levels by Frequency (Watt-Hz) Mode Mode PDIS Distance Protection Mode

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Class Description General Category PTOF Time Over-Frequency Protection Mode PTOV Time Over-Voltage Protection Mode PTUF Time Under-Frequency Protection Mode PTUV Time Under-Voltage Protection Mode CALH Common Alarms Monitor DPST Status Information at the Connection Point Monitor LCCH Communications Channel Monitor MMDC DC Measurements Monitor MMTR Energy Metering Monitor MMXU Measurement Unit (RMS measurements) Monitor MMXN Measurement Unit (Non-Phase Related RMS) Monitor

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2.2 Points List This section describes the points list to be used by DNP3 outstations controlling a DER. Previous versions of this profile specified that any device claiming to implement this DNP3 application note were required to report all the DNP3 object instances (points) described in the document. The points list was therefore identical for all compliant outstations. This is no longer the case. This version of the profile instead specifies a points list that varies depending on the number of each type of component implemented in the DER and reported by the outstation. The types of DER components described by this profile are the following, as described in 2.1.1: • Controller (the DNP3 outstation) • Meters • DER Units • Inverters • Batteries

2.2.1 Point Blocks Each type of DER component has a set , or “block” of points associated with it. To be compliant with this application note, the outstation shall implement these points in the order described in this profile. Figure 4 illustrates how the points shall be organized. As shown in Figure 4 and Table 3, the points are also grouped in categories by their purpose. Note that the SCADA and Configuration category points are Mandatory (M), while the other points are Optional (O).

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Table 3 – Categories of Points Point Category M/O Description

SCADA and M These are the points associated with the Controller. They define: Configuration • The nameplate limits of the DER. • The current physical configuration (structure) of the DER, including values that indicate the number of point blocks of Meters, DER Units, Inverters and Batteries (Historical Points) implemented by the outstation. • The settings controlling all the DER modes and functions as described in 2.3, 2.4, 2.5, 2.6 and 2.7. Refer to 2.3.1 and the note below regarding non-implemented modes and functions. • The current status of all the DER modes and functions. • The definition of curves for controlling DER operation, such as Volt/VAR curves. Refer to 2.3.3. • The measurements made by the System Meter. The location of the System Meter is illustrated in Figure 1 on page 12. NOTE: An outstation may claim to implement this DNP3 application note without implementing all the inverter modes and functions. See 2.3.1 for details. Scheduling O Points which permit power scheduling personnel to effectively control the behavior of the DER over specific time periods. Schedules are implemented by the Controller. Historical O Detailed measurement and performance data which may be valuable to record in an operational historian but might not be useful to a system operator. These points are associated with the Meters, DER Units, Inverters, and Batteries in the DER. Vendor-Specific O If an outstation reports additional data points, they must be added after the last point index described in this specification that is appropriate to that DER’s implementation level, as illustrated in Figure 5. This capability permits an outstation to add to their outstation any proprietary or innovative functionality that is not part of this standard.

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0 1 Meter #1's Points 2 SCADA and Configuration Points 3 Meter #2's Points

S+0 S+1 S+3 Meter #N s Points Scheduling Points S+3 DER Unit #1's Points S+N H+0 DER Unit #2's Points H+1 H+2

H+3

DER Unit #N s Points

Inverter #1's Points Historical Points Inverter #2's Points

Inverter #N s Points

H+N Battery #1's Points

Battery #2's Points

Battery #N s Points

Figure 4 – Organization of the Points List

The naming of these point categories is somewhat arbitrary; since DNP3 is a SCADA protocol, any of these points categories can reasonably be considered “SCADA” points. However, the terminology is useful to describe which points are implemented in a given outstation. Table 4 describes the permitted levels of implementation of this profile. Table 4 – Permitted Implementation Levels DER Profile Configuration Implementation Level

1 Configuration + SCADA Points Only

2 Configuration + SCADA + Scheduling Points

3 Configuration + SCADA + Scheduling + Historical Points

The following rules apply to DER Profile Implementation Levels: 1. Other combinations of standard points are not permitted, (e.g. implementing Configuration + SCADA + Historical without Scheduling is not allowed) 2. The outstation may add vendor-specific points on the end of the list as shown in Figure 5. 3. The DER Profile Implementation Level of the outstation shall be reported by the outstation in AI1. Page 19 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

NOTE: This DER Profile Implementation Level should not be confused with the overall DNP3 implementation level of this profile, which is DNP3-L2, regardless of which points are implemented by the outstation.

Figure 5 – Placement of Vendor-specific points

NOTE: This profile specification has a version number, which is always available to the master as the first analog input point (AI0).

The intent of this application note is that for a given DER Profile Version Number, DER Profile Implementation Level, and given numbers of implemented Meters, DER Units, Inverters and Batteries, the system engineer configuring the master shall always know exactly which non-vendor-specific data points are implemented by the outstation, and in what order. Furthermore, this information shall be available over the DNP3 protocol (in AI0,AI1, and AI24 through AI28) so masters can be implemented such that they can verify their internal configuration against that reported by the outstation. The table formats and protocol parameters specified in this profile are taken from the standard DNP3 Device Profile document. The section numbers in the “protocol options” tables are references within that document.

2.2.2 Numbering Points As noted in the previous section, the points lists defined in this profile are not fixed, but vary depending on the components and structure of the DER. Therefore, only the SCADA and Configuration (System) points have fixed absolute point numbers. All the other point numbers are calculated relative to others.

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Table 5 lists the abbreviations used in the points lists to identify the point numbers, and the length of each repeating block of points. In the points list tables, an expression such as “HM + hmbi(m) + 2” means “Take the starting index of the historical meter points, add the number of (historical) binary input points per meter multiplied by the block number of this particular meter (where meter blocks are numbered starting at 0) and add two”. Note the expressions used may appear somewhat inconsistent – e.g. “historical meters” vs. “DER units, historical” – but the same expression is always used to refer to the same point. Note that in this profile there are 100 pairs of points (time and value) always reserved for editing schedules, and 100 pairs of points (x-y values) always reserved for editing curves. The numbers in Table 5 will always be the same for a given DER Profile Version Number (AI0). Table 5 – Abbreviations and constants used in numbering the points lists Starting Point Category Component Length of Block Block Number Point Binary inputs 102 SCADA and Binary outputs 38 Not Configuration 0 Counters 4 Does not repeat applicable (System) Analog inputs 534 Analog outputs 432 Binary inputs 9 Does not repeat Binary outputs 8 Does not repeat Analog inputs per system 12 Does not repeat Not Schedules S Analog inputs per schedule point 2 sp – schedule point applicable Analog inputs per schedule 3 s - schedule Analog outputs per system 9 Does not repeat Analog outputs per schedule point 2 sp – schedule point hmbi – binary inputs per meter 13 hmc – counters per meter 4 Historical Meters HM m - meter hmai- analog inputs per meter 37 hmao – analog outputs per meter 12 duhbi – binary inputs per DER unit 4 Historical DER Units HDU u - unit duhai – analog inputs per DER unit 14 ihbi – binary inputs per inverter 35 Historical Inverters HI ihai – analog inputs per inverter 33 i - inverter ihao – analog outputs per inverter 12 bhbi – binary inputs per battery 54 Historical Batteries HB bhai – analog inputs per battery 27 b - battery bhao – analog outputs per battery 4

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2.2.3 Event Classes This profile uses the following criteria for assigning points to default classes: Table 6 – Default event classes in this profile Class Criteria Critical data. Alarms and other events 1 requiring immediate action. 2 Feedback 3 Measurements and Configuration

If supported by the outstation, the operator/engineer may choose to change these defaults at runtime using the ASSIGN CLASS function code from the master. However, the outstation is not required to support ASSIGN CLASS because it is not a DNP3-L2 function, as discussed in 1.2. The outstation may alternately permit event classes to be assigned by pre-configuration, or make them fixed.

2.2.4 IEC 61850 Mapping The rightmost columns of the points list tables show how each point would be mapped onto an IEC 61850 gateway. The values in the columns are as shown in Table 7.

Table 7 – Meanings of the IEC 61850 Columns Column Meaning LN Class Logical node class LN Inst Logical node instance Data Object Data object within the logical node CDC Common data class of the data object This is the standardized IEC 61850 name of the Unique point. The utility may add prefixes to this name to String specify a particular location or instance.

The IEC 61850 Common Data Classes are defined in the IEC 61850-7-3 specification. Table 8 lists the names of those used in this profile. Table 8 – IEC 61850 Common Data Classes referenced by this profile CDC Name APC Analog setpoint controllable ASG Analog setting CSG Curve setting DPC Double point controllable ENG Enumerated setting ENS Enumerated status INC Integer status controllable ING Integer setting INS Integer status MV Measured value SPC Single point controllable SPS Single point status WYE Wye-Connected 3-phase measurement

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2.2.5 Binary Inputs Table 9 lists the binary input points to be used in the DNP3 Profile for DERs. Table 10 specifies the options to be used by outstations when reporting these points. Note that these are read/only values that represent the current state of the system. Some of these values can be changed using corresponding binary output points listed in section 2.2.6. The point numbers for the writeable values and the read/only values are not the same.

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Table 9 – Binary Input Points List Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class System Binary Inputs Alarm: Communica- System Communication BI0 1 Normal tions error LCCH ChLiv SPS LCCH.ChLiv 2.4.1 Error exists in the outstation

Alarm: One or System Has Priority 1 No P1 Alarms BI1 1 More P1 CALH GrAlm SPS CALH.GrAlm 2.4.1 Alarms Active Alarms Active

Alarm: One or System Has Priority 2 No P2 Alarms BI2 1 More P2 CALH GrWrn SPS CALH.GrWrn 2.4.1 Alarms Active Alarms Active Alarm: One or System Has Priority 3 No P3 Alarms BI3 1 More P3 CALH GrInd SPS CALH.GrInd 2.4.1 Alarms Active Alarms Active Storage State of Charge at Maximum. Maximum BI4 1 Normal Alarm DSTO SohHiWrn SPS DSTO.SohHiWrn 2.6.2 Usable State of Charge reached. Storage State of Charge is Too High. Maximum BI5 Reserve Percentage (of 1 Normal Alarm DSTO SocHiAlm SPS DSTO.SocHiAlm 2.6.2 usable capacity) reached. Storage State of Charge is Too Low. Minimum BI6 Reserve Percentage (of 1 Normal Alarm DSTO SocLoAlm SPS DSTO.SocLoAlm 2.6.2 usable capacity) reached. Storage State of Charge is Depleted. Minimum BI7 1 Normal Alarm DSTO SohLoAlm SPS DSTO.SohLoAlm 2.6.2 Usable State of Charge Reached.

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Storage Internal BI8 Temperature is Too 1 Normal Alarm DBAT IntnTmpHiAlm SPS DBAT.IntnTmpHiAlm 2.4.1 High Storage External DBAT ExtTmpHiAlm SPS DBAT.ExtTmpHiAlm BI9 (Ambient) Temperature 1 Normal Alarm 2.4.1 is Too High System Is In Local State. System has been locked by a local operator which prevents other operators from System not in System in DEROpSt.disconnected DSTO.DEROpSt.disconnected and in BI10 executing commands. 2 DSTO ENS 2.4.6 local state local state and in maintenance maintenance Note: Local State is also sometimes referred to as Maintenance State. Local State overrides Lockout State. System Is In Lockout State. System has been locked by an operator such that other System not System DEROpSt.disconnected BI11 operators may not 2 DSTO ENS DSTO.DEROpSt.disconnected and blocked 2.4.6 locked out locked out and blocked execute commands. Lockout State is also sometimes referred to as Blocked State System Is Starting Up. Start Set to 1 when a BO Not Starting command has DEROpSt.starting and BI12 "System Initiate Start-up 2 DSTO ENS DSTO.DEROpSt.starting and synchronizing 2.4.6 Up been synchronizing Sequence" command received. has been received. System Is Stopping Emergency Set to 1 when an BO stop BI13 "System Execute Stop" 2 Not Stopping command has DSTO DEROpSt.stopping ENS DSTO.DEROpSt.stopping 2.4.6 command has been been received. received.

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class System is Started (Return to Service). If any of the DER Units are started, then true. DEROpSt.connected BI14 2 Null Started DSTO ENS DSTO.DEROpSt.connected and idle 2.4.6 DER Units in the and idle maintenance operational state are excluded. System is Stopped (Cease to Energize). If all of the DER Units are stopped, then true. DEROpSt.ceased to BI15 2 Null Stopped DSTO ENS DSTO.DEROpSt.ceased to energize 2.4.6 DER Units in the energize maintenance operational state are excluded. Start Start DSTO PrmConn SPC DSTO.PrmConn System Permission to BI16 2 Permission Permission 2.4.6 Start Status Not Granted Granted Stop Stop DSTO PrmDscon SPC DSTO.PrmDscon System Permission to BI17 2 Permission Permission 2.4.6 Stop Status Not Granted Granted DER is Connected and Idle- DSTO DEROpSt.connected ENS DSTO.DEROpSt.connected and idle BI18 2 Null 2.4.6 Idle Connected and idle DER is Connected and On- DSTO DEROpSt.connected ENS DSTO.DEROpSt.connected and generating BI19 2 Null 2.4.6 Generating Connected and generating DER is Connected and On-Charging- DSTO DEROpSt.connected ENS DSTO.DEROpSt.connected and consuming BI20 2 Null 2.4.6 Charging Connected and consuming DER is Off but Available DSTO DEROpSt.disconnected ENS DSTO.DEROpSt.disconnected and available BI21 2 Null Off-Available 2.4.6 to Start and available DER is Off and Not Off-Not- DSTO DEROpSt.disconnected ENS DSTO.DEROpSt.disconnected and stand-by BI22 2 Null 2.4.6 Available to Start Available and stand-by DER BI23 Connect/Disconnect 2 Open Closed DSTO DEROpSt.off ENS DSTO.DEROpSt.off 2.4.4 Switch Closed Status

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class DER Connect/Disconnect BI24 2 Not Moving Moving CSWI Pos DPC CSWI.Pos 2.4.4 Switch Movement Status Islanded Mode. Determines how the DER behaves when in an Islanded configuration. <0> Isochronous Mode. DER attempts to control voltage and frequency independent of configured curves Isochronous BI25 and settings up to the 3 Droop Mode DSTO IsldCtlFol SPG DSTO.IsldCtlFol 2.11 Mode limits of the machine's capabilities in order to achieve the AO Reference Voltage and AO nominal frequency. <1> Droop Mode. DER acts as a follower using Volt/VAR and Freq/Watt curves.

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Sensed Grid Config Detection Enabled. If Enabled, the DER may independently change its Active Settings Group based on locally observed grid conditions. BI26 3 Not Ready Ready DECP ECPIsldAuto SPG DECP.ECPIsldAuto 2.11 <0> No Autonomous Detection. <1> Autonomous Detection. Inverter's Active Settings Group may differ from the Requested Settings Group Storage Capacity Units. Determines whether Amp-hrs BI27 energy storage values 3 Watt-hrs DSTO AGra SPG DSTO.AGra 2.6.2 (default) are expressed in units of Amp-hrs or Watt-hrs. Time Constant Mode. Indicates whether Time Constant Ramp Open Loop BI28 parameters are 3 Response 3Tau Value DSTO OpnLoopTau SPG DSTO.OpnLoopTau 2.3.4 interpreted as Open Time Loop Response times or 3Tau values. Power Factor Excitation Producing Absorbing BI29 When Discharging / 2 DFPF PFGnExtSet SPG DFPF.PFGnExtSet 2.7 VARs - Q1 VARs - Q4 Generating

Power Factor Excitation Producing Absorbing BI30 2 DFPF PFLodExtSet SPG DFPF.PFLodExtSet 2.7 When Charging VARs – Q2 VARs – Q3

Supports Low/High Not BI31 Voltage Ride-Through 3 Supported DHVT ENS 2.3.1 Supported -- -- Mode

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Supports Low/High Not BI32 Frequency Ride- 0 Supported DHFT ENS 2.3.1 Supported -- -- Through Mode Supports Dynamic Not BI33 Reactive Current 0 Supported DRGS ENS 2.3.1 Supported -- -- Support Mode Supports Dynamic Volt- Not BI34 0 Supported DVWD ENS 2.3.1 Watt Mode Supported -- -- Supports Frequency- Not BI35 0 Supported DHFW ENS 2.3.1 Watt Mode Supported -- -- Supports Active Power Not BI36 0 Supported DWLM ENS 2.3.1 Limit Mode Supported -- -- Supports Not BI37 0 Supported DWGC ENS 2.3.1 Charge/Discharge Mode Supported -- -- Supports Coordinated Not BI38 0 Supported DTCD ENS 2.3.1 Charge/Discharge Mode Supported -- -- Supports Active Power Not BI39 0 Supported DLFL ENS 2.3.1 Response Mode #1 Supported -- -- Supports Active Power Not BI40 0 Supported DGFL ENS 2.3.1 Response Mode #2 Supported -- -- Supports Active Power Not BI41 0 Supported DGFL ENS 2.3.1 Response Mode #3 Supported -- -- Supports Automatic Not BI42 Generation Control 0 Supported DAGC ENS 2.3.1 Supported -- -- Mode Supports Active Power Not BI43 0 Supported DWSM ENS 2.3.1 Smoothing Mode Supported -- -- Supports Volt-Watt Not BI44 0 Supported DVWC ENS 2.3.1 Mode Supported -- -- Supports Frequency- Not BI45 0 Supported DFWC ENS 2.3.1 Watt Curve Mode Supported -- --

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Supports Constant VArs Not BI46 0 Supported DVAR ENS 2.3.1 Mode Supported -- -- Supports Fixed Power Not BI47 0 Supported DFPF ENS 2.3.1 Factor Mode Supported -- -- Supports Volt-VAR Not BI48 0 Supported DVVC ENS 2.3.1 Control Mode Supported -- -- Supports Watt-VAr Not BI49 0 Supported DWVR ENS 2.3.1 Mode Supported -- -- Supports Power Factor Not BI50 0 Supported DPFC ENS 2.3.1 Correction Mode Supported -- -- Not BI51 Supports Pricing Mode 0 Supported DPRG ENS 2.3.1 Supported -- -- Overvoltage Disconnect Blocked BI52 1 Not Blocked PTOV Blk SPS PTOV.Blk 2.5.1 Protection Blocked (Disabled) Overvoltage Disconnect Started BI53 1 Not Started PTOV Str.general ACD PTOV.Str.general 2.5.1 Protection Started (Evaluating) Operated Overvoltage Disconnect BI54 1 Not Operated (Disconnecte PTOV Op.general ACT PTOV.Op.general 2.5.1 Protection Operated d) Undervoltage Blocked BI55 Disconnect Protection 1 Not Blocked PTUV Blk SPS PTUV.Blk 2.5.1 (Disabled) Blocked Undervoltage Started BI56 Disconnect Protection 1 Not Started PTUV Str.general ACD PTUV.Str.general 2.5.1 (Evaluating) Started Undervoltage Operated BI57 Disconnect Protection 1 Not Operated (Disconnecte PTUV Op.general ACT PTUV.Op.general 2.5.1 Operated d) Over Frequency Blocked BI58 Disconnect Protection 1 Not Blocked PTOF Blk SPS PTOF.Blk 2.5.2 (Disabled) Blocked

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Over Frequency Started BI59 Disconnect Protection 1 Not Started PTOF Str.general ACD PTOF.Str.general 2.5.2 (Evaluating) Started Over Frequency Operated BI60 Disconnect Protection 1 Not Operated (Disconnecte PTOF Op.general ACT PTOF.Op.general 2.5.2 Operated d) Under Frequency Blocked BI61 Disconnect Protection 1 Not Blocked PTUF Blk SPS PTUF.Blk 2.5.2 (Disabled) Blocked Under Frequency Started BI62 Disconnect Protection 1 Not Started PTUF Str.general ACD PTUF.Str.general 2.5.2 (Evaluating) Started Under Frequency Operated BI63 Disconnect Protection 1 Not Operated (Disconnecte PTUF Op.general ACT PTUF.Op.general 2.5.2 Operated d) Operating Mode - BI64 Low/High Voltage Ride- 2 Disabled Enabled DHVT ModEna SPC DVRT.ModEna 2.5.1 Through Operating Mode - BI65 Low/High Frequency 2 Disabled Enabled DHFT ModEna SPC DFRT.ModEna 2.5.2 Ride-Through Operating Mode - Dynamic Reactive BI66 2 Disabled Enabled DRGS ModEna ENC DRGS.ModEna 2.5.3 Current Support Enabled Operating Mode - BI67 Dynamic Volt-Watt 2 Disabled Enabled DVWD ModEna SPC DVWD.ModEna 2.5.5 Enabled Operating Mode - BI68 Frequency-Watt 2 Disabled Enabled DHFW ModEna SPC DFWP.ModEna 2.5.3 Enabled Operating Mode - Active BI69 2 Disabled Enabled DWLM ModEna SPC DWLM.ModEna 2.6.1 Power Limit Enabled

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Operating Mode - BI70 Charge/Discharge 2 Disabled Enabled DWGC ModEna SPC DWGC.ModEna 2.6.2 Enabled Operating Mode - Coordinated Charge / BI71 2 Disabled Enabled DPKP ModEna SPC DTCD.ModEna 2.6.3 Discharge Management Enabled Operating Mode - Active BI72 Power Response Mode 2 Disabled Enabled DGFL ModEna SPC DLFL.ModEna 2.6.4.1 #1 Enabled Operating Mode - Active BI73 Power Response Mode 2 Disabled Enabled DLFL ModEna SPC DGFL.ModEna 2.6.4.2 #2 Enabled Operating Mode - Active BI74 Power Response Mode 2 Disabled Enabled DGFL ModEna SPC DGFL.ModEna 2.6.4.2 #3 Enabled Operating Mode - BI75 Automatic Generation 2 Disabled Enabled DAGC ModEna SPC DAGC.ModEna 2.6.5 Control Enabled Operating Mode - Active BI76 Power Smoothing 2 Disabled Enabled DWSM ModEna SPC DWSM.ModEna 2.6.6 Enabled Operating Mode - Volt- BI77 2 Disabled Enabled DVWC ModEna SPC DVWC.ModEna 2.6.7 Watt Enabled Operating Mode - BI78 Frequency-Watt Curve 2 Disabled Enabled DHFW ModEna SPC DFWC.ModEna 2.6.8 Enabled Operating Mode - BI79 2 Disabled Enabled DVAR ModEna SPC DVAR.ModEna 2.7.1 Constant VArs Enabled Operating Mode - Fixed BI80 2 Disabled Enabled DFPF ModEna SPC DFPF.ModEna 2.7.2 Power Factor Enabled Operating Mode - Volt- BI81 2 Disabled Enabled DVVR ModEna SPC DVVC.ModEna 2.7.3 VAR Control Enabled

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Operating Mode - Watt- BI82 2 Disabled Enabled DWVR ModEna SPC DWVR.ModEna 2.7.4 VAr Enabled Operating Mode - BI83 Power Factor Correction 2 Disabled Enabled DPFC ModEna SPC DPFC.ModEna 2.7.5 Enabled Operating Mode - BI84 2 Disabled Enabled DPRG ModEna SPC DPRG.ModEna 2.8 Pricing Enabled Operating Mode - Event-Based Reactive BI85 2 Disabled Enabled DRGS ModEna SPC RDGS.ModEna 2.5.4.3 Current Support Enabled Frequency-Watt Mode - BI86 2 Disabled Enabled DHFW HysEna SPG DFWP.HysEna 2.5.3 Use Hysteresis Frequency-Watt Mode - BI87 2 Not Active Active SnptEna SPG DFWP.SnptEna 2.5.3 Snapshot of Power DHFW Frequency-Watt Curve BI88 2 Disabled Enabled DLFW HysEna SPG DFWC.HysEna 2.6.8 Mode - Use Hysteresis Frequency-Watt Curve BI89 Mode - Snapshot of 2 Not Active Active DLFW SnptEna SPG DFWP.SnptEna 2.6.8 Power Charge/Discharge Mode - Use Ramp Rates. Indicates whether or not Use Time Use Ramp BI90 Charge/Discharge 2 DWGC UseRmpRte SPG DWGC.UseRmpRte 2.6.2 Constants Rates should use specified ramp rates or time constants AGC Mode - Use Ramp Rates. Indicates whether or not Use Time Use Ramp BI91 charge/discharge 2 DAGC UseRmpRte SPG DAGC.UseRmpRte 2.6.5 Constants Rates should use specified ramp rates or time constants

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Use Ramp Volt-Watt - Use Ramp Use Time Rates AND BI92 Rates and Time 2 DVWC UseRmpRte SPG DVWC.UseRmpRte 2.7.1 Constants Time Constants Constants Volt-VAr Enable BI93 Autonomous Voltage 2 Disabled Enabled DVVR VRefAdjEna SPG DVWC.UseRmpRte 2.7.3 Reference Adjustment System Meter Active BI94 1 Normal Alarm MMXU TotW.range MV MMXU.TotW.range 2.4.3 Power is Too High System Meter Active BI95 1 Normal Alarm MMXU TotW.range MV MMXU.TotW.range 2.4.3 Power is Too Low System Meter Reactive BI96 1 Normal Alarm MMXU TotVAr.range MV MMXU.TotVAr.range 2.4.3 Power is Too High System Meter Reactive BI97 1 Normal Alarm MMXU TotVAr.range MV MMXU.TotVAr.range 2.4.3 Power is Too Low System Meter Power BI98 1 Normal Alarm MMXU TotPF.range MV MMXU.TotPF.range 2.4.3 Factor is Too High System Meter Power BI99 1 Normal Alarm MMXU TotPF.range MV MMXU.TotPF.range 2.4.3 Factor is Too Low System Meter Phase A BI100 1 Normal Alarm MMXU PhV.phsA.range WYE MMXU.PhV.phsA.range 2.4.3 Voltage is Too High System Meter Phase A BI101 1 Normal Alarm MMXU PhV.phsA.range WYE MMXU.PhV.phsA.range 2.4.3 Voltage is Too Low System Meter Phase B BI102 1 Normal Alarm MMXU PhV.phsB.range WYE MMXU.PhV.phsB.range 2.4.3 Voltage is Too High System Meter Phase B BI103 1 Normal Alarm MMXU PhV.phsB.range WYE MMXU.PhV.phsB.range 2.4.3 Voltage is Too Low System Meter Phase C BI104 1 Normal Alarm MMXU PhV.phsC.range WYE MMXU.PhV.phsC.range 2.4.3 Voltage is Too High System Meter Phase C BI105 1 Normal Alarm MMXU PhV.phsC.range WYE MMXU.PhV.phsC.range 2.4.3 Voltage is Too Low

Page 34 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Normal: No Alarm: Active System Meter Active BI106 1 Communicati LCCH ChLiv SPS LCCH.ChLiv 2.4.3 Communication Error Communicati ons Error ons Error Selected Curve is Curve is Not Curve is BI107 1 n/a n/a n/a n/a 2.3.3 Referenced by a Mode Referenced Referenced Schedule Binary Inputs S (S=108 for this Selected Schedule Is 2 Not Ready Ready FSCH SchdSt.3 ENS FSCH.SchdSt.3 2.9 version of the Ready specifcation) Selected Schedule is S+1 2 Not validated Validated FSCH SchdSt.2 ENS FSCH.SchdSt.2 2.9 Validated Selected Schedule Do Not S+2 2 Repeat FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Repeat Weekly Sunday Repeat Selected Schedule Do Not S+3 2 Repeat FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Repeat Weekly Monday Repeat Selected Schedule Do Not S+4 Repeat Weekly 2 Repeat FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Repeat Tuesday Selected Schedule Do Not S+5 Repeat Weekly 2 Repeat FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Repeat Wednesday Selected Schedule Do Not S+6 Repeat Weekly 2 Repeat FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Repeat Thursday Selected Schedule Do Not S+7 2 Repeat FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Repeat Weekly Friday Repeat Selected Schedule Do Not S+8 Repeat Weekly 2 Repeat FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Repeat Saturday Historian Meter Binary Inputs

Page 35 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Active Power at Meter HM 1 Normal Alarm MMXU TotW.range MV MMXU.TotW.range 2.4.3 #1 is Too High Active Power at Meter HM + 1 1 Normal Alarm MMXU TotW.range MV MMXU.TotW.range 2.4.3 #1 is Too Low Reactive Power at HM + 2 1 Normal Alarm MMXU TotVAr.range MV MMXU.TotVAr.range 2.4.3 Meter #1 is Too High Reactive Power at HM + 3 1 Normal Alarm MMXU TotVAr.range MV MMXU.TotVAr.range 2.4.3 Meter #1 is Too Low Power Factor at Meter HM + 4 1 Normal Alarm MMXU TotPF.range MV MMXU.TotPF.range 2.4.3 #1 is Too High Power Factor at Meter HM + 5 1 Normal Alarm MMXU TotPF.range MV MMXU.TotPF.range 2.4.3 #1 is Too Low Phase A Voltage at HM + 6 1 Normal Alarm MMXU PhV.phsA.range WYE MMXU2.PhV.phsA.range 2.4.3 Meter #1 is Too High Phase A Voltage at HM + 7 1 Normal Alarm MMXU PhV.phsA.range WYE MMXU2.PhV.phsA.range 2.4.3 Meter #1 is Too Low Phase B Voltage at HM + 8 1 Normal Alarm MMXU PhV.phsB.range WYE MMXU2.PhV.phsB.range 2.4.3 Meter #1 is Too High Phase B Voltage at HM + 9 1 Normal Alarm MMXU PhV.phsB.range WYE MMXU2.PhV.phsB.range 2.4.3 Meter #1 is Too Low Phase C Voltage at HM + 10 1 Normal Alarm MMXU PhV.phsC.range WYE MMXU2.PhV.phsC.range 2.4.3 Meter #1 is Too High Phase C Voltage at HM + 11 1 Normal Alarm MMXU PhV.phsC.range WYE MMXU2.PhV.phsC.range 2.4.3 Meter #1 is Too Low Normal: No Alarm: Active Meter #1 Active HM + 12 1 Communicati LCCH ChLiv SPS LCCH.ChLiv 2.4.3 Communication Error Communicati ons Error ons Error

Meter #2 . . . Meter #m- … 1 points

Page 36 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Active Power at Meter HM + mhbi(m) 1 Normal Alarm MMXU TotW.range MV MMXUn.TotW.range 2.4.3 #m is Too High Active Power at Meter HM + mhbi(m) + 1 1 Normal Alarm MMXU TotW.range MV MMXUn.TotW.range 2.4.3 #m is Too Low Reactive Power at HM + mhbi(m) + 2 1 Normal Alarm MMXU TotVAr.range MV MMXUn.TotVAr.range 2.4.3 Meter #m is Too High Reactive Power at HM + mhbi(m) + 3 1 Normal Alarm MMXU TotVAr.range MV MMXU.TotVAr.range 2.4.3 Meter #m is Too Low Power Factor at Meter HM + mhbi(m) + 4 1 Normal Alarm MMXU TotPF.range MV MMXU.TotPF.range 2.4.3 #m is Too High Power Factor at Meter HM + mhbi(m) + 5 1 Normal Alarm MMXU TotPF.range MV MMXU.TotPF.range 2.4.3 #m is Too Low Phase A Voltage at HM + mhbi(m) + 6 1 Normal Alarm MMXU PhV.phsA.range WYE MMXU2.PhV.phsA.range 2.4.3 Meter #m is Too High Phase A Voltage at HM + mhbi(m) + 7 1 Normal Alarm MMXU PhV.phsA.range WYE MMXU2.PhV.phsA.range 2.4.3 Meter #m is Too Low Phase B Voltage at HM + mhbi(m) + 8 1 Normal Alarm MMXU PhV.phsB.range WYE MMXU2.PhV.phsB.range 2.4.3 Meter #m is Too High Phase B Voltage at HM + mhbi(m) + 9 1 Normal Alarm MMXU PhV.phsB.range WYE MMXU2.PhV.phsB.range 2.4.3 Meter #m is Too Low Phase C Voltage at HM + mhbi(m) + 10 1 Normal Alarm MMXU PhV.phsC.range WYE MMXU2.PhV.phsC.range 2.4.3 Meter #m is Too High Phase C Voltage at HM + mhbi(m) + 11 1 Normal Alarm MMXU PhV.phsC.range WYE MMXU2.PhV.phsC.range 2.4.3 Meter #m is Too Low Normal: No Alarm: Active Meter #m Active HM + mhbi(m) + 12 1 Communicati LCCH ChLiv SPS LCCH.ChLiv 2.4.3 Communication Error Communicati ons Error ons Error DER Unit Historian Points DER Unit #1 Is In Not in In DEROpSt.disconnected DSTO.DEROpSt.disconnected and in HDU Maintenance 2 DSTO ENS 2.4.6 Maintenance Maintenance and in maintenance maintenance Operational State

Page 37 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Alarm: One or DER Unit #1 Has No P1 Alarms HDU +1 1 More P1 CALH GrAlm SPS CALH.GrAlm 2.4.3 Priority 1 Alarms Active Alarms Active Alarm: One or DER Unit #1 Has No P2 Alarms HDU +2 1 More P2 CALH GrWrn SPS CALH.GrWrn 2.4.3 Priority 2 Alarms Active Alarms Active Alarm: One or DER Unit #1 Has No P3 Alarms HDU +3 1 More P3 CALH GrInd SPS CALH.GrInd 2.4.3 Priority 3 Alarms Active Alarms Active

. DER Unit #2 . . . DER . Unit #u-1 points . .

DER Unit #u Is In Not in In DEROpSt.disconnected DSTO.DEROpSt.disconnected and in HDU + duhbi(u) Maintenance 1 DSTO ENS 2.4.6 Maintenance Maintenance and in maintenance maintenance Operational State Alarm: One or DER Unit #u Has No P1 Alarms HDU + duhbi(u) + 1 1 More P1 CALH GrAlm SPS CALH.GrAlm 2.4.3 Priority 1 Alarms Active Alarms Active Alarm: One or DER Unit #u Has No P2 Alarms HDU + duhbi(u) + 2 1 More P2 CALH GrWrn SPS CALH.GrWrn 2.4.3 Priority 2 Alarms Active Alarms Active Alarm: One or DER Unit #u Has No P3 Alarms HDU + duhbi(u) + 3 1 More P3 CALH GrInd SPS CALH.GrInd 2.4.3 Priority 3 Alarms Active Alarms Active Inverter Historian Binary Inputs Inverter #1 Active HI Power Output is Too 1 Normal Alarm MMXU TotW.range MV MMXU1.TotW.range 2.4.3 High Inverter #1 Active HI + 1 Power Output is Too 1 Normal Alarm MMXU TotW.range MV MMXU1.TotW.range 2.4.3 Low Inverter #1 Reactive HI + 2 Power Output is Too 1 Normal Alarm MMXU TotVAr.range MV MMXU1.TotVAr.range 2.4.3 High

Page 38 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Inverter #1 Reactive HI + 3 Power Output is Too 1 Normal Alarm MMXU TotVAr.range MV MMXU1.TotVAr.range 2.4.3 Low Inverter #1 Current HI + 4 Output Frequency is 1 Normal Alarm MMXU Hz.range MV MMXU1.Hz.range 2.4.3 Too High Inverter #1 Current HI + 5 Output Frequency is 1 Normal Alarm MMXU Hz.range MV MMXU1.Hz.range 2.4.3 Too Low Inverter #1 DC Input HI + 6 1 Normal Alarm MMDC Watt.range MV MMDC1.Watt.range 2.4.3 Power is Too High Inverter #1 DC Input HI + 7 1 Normal Alarm MMDC Watt.range MV MMDC1.Watt.range 2.4.3 Power is Too Low Inverter #1 DC Current HI + 8 1 Normal Alarm MMDC Amp.range MV MMDC1.Amp.range 2.4.3 Level is Too High Inverter #1 DC Current HI + 9 1 Normal Alarm MMDC Amp.range MV MMDC1.Amp.range 2.4.3 Level is Too Low Inverter #1 DC Input HI + 10 1 Normal Alarm MMDC Vol.range MV MMDC1.Vol.range 2.4.3 Voltage is Too High Inverter #1 DC Input HI + 11 1 Normal Alarm MMDC Vol.range MV MMDC1.Vol.range 2.4.3 Voltage is Too Low Inverter #1 DNP3 Power Overexcited Underexcited Factor Excitation. (producing (absorbing HI + 12 1 DSTO PFExtSet SPG DSTO.PFExtSet 2.7 Operating quadrant of VARs - VARs - the inverter. Q1/Q2) Q3/Q4) Inverter #1 HI + 13 1 Normal Alarm LCCH ChLiv SPS LCCH.ChLiv 2.4.3 Communication Error Inverter #1 Is In Local DEROpSt.disconnected DSTO.DEROpSt.disconnected and in HI + 14 1 Normal Alarm DSTO ENS 2.10.1 Control Mode and in maintenance maintenance Inverter #1 Is DC HI + 15 1 Normal Alarm DINV InvSwiAlm SPS DINV.InvSwiAlm 2.4.3 Contactor Closed Inverter #1 Ground HI + 16 1 Normal Alarm PDIS Str ACD PDIS.Str 2.4.3 Fault Alarm

Page 39 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Inverter #1 DC Over HI + 17 1 Normal Alarm MMDC Vol.range MV MMDC.Vol.range 2.4.3 Voltage Alarm Inverter #1 DC Under HI + 18 1 Normal Alarm MMDC Vol.range MV MMDC.Vol.range 2.4.3 Voltage Alarm Inverter #1 AC HI + 19 1 Normal Alarm DINV InvACLosAlm SPS DINV.InvACLosAlm 2.4.4 Disconnect Warning Inverter #1 DC HI + 20 1 Normal Alarm DINV InvDCLosAlm SPS DINV.InvDCLosAlm 2.4.4 Disconnect Warning Inverter does Inverter #1 Grid not detect HI + 21 1 Normal DINV InvGriLosAlm SPS DINV.InvGriLosAlm 2.4.4 Disconnect Warning power on the grid Inverter #1 Cabinet HI + 22 1 Normal Alarm SPSE GteSt.open ENS SPSE.GteSt.open 2.4.3 Open Warning Inverter #1 Manual HI + 23 1 Normal Alarm DINV InvManStopSt SPS DINV.InvManStopSt 2.4.3 Shutdown Warning Inverter #1 Over HI + 24 1 Normal Alarm DINV EnclTmp.range MV DINV.EnclTmp.range 2.4.3 Temperature Alarm Inverter #1 Under HI + 25 1 Normal Alarm DINV EnclTmp.range MV DINV.EnclTmp.range 2.4.3 Temperature Alarm Inverter #1 Over HI + 26 1 Normal Alarm MMXU Hz.range MV MMXU1.Hz.range 2.4.3 Frequency Alarm Inverter #1 Under HI + 27 1 Normal Alarm MMXU Hz.range MV MMXU1.Hz.range 2.4.3 Frequency Alarm Inverter #1 AC Over HI + 28 1 Normal Alarm MMXU PhV.PhsA.range WYE MMXU.PhV.PhsA.range 2.4.3 Voltage Alarm Inverter #1 AC Under HI + 29 1 Normal Alarm MMXU PhV.PhsA.range WYE MMXU.PhV.PhsA.range 2.4.3 Voltage Alarm Inverter #1 Blown String HI + 30 1 Normal Alarm XFUS FuSt SPS XFUS.FuSt 2.4.3 Fuse Alarm Inverter #1 Memory HI + 31 1 Normal Alarm #SAlarMML .#SAlarMML 2.4.3 Loss Alarm

Page 40 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Inverter #1 Hardware HI + 32 1 Normal Alarm DINV TestRsl SPS DINV.TestRsl 2.4.3 Test Failure

HI + 33 Inverter #1 Other Alarm 1 Normal Alarm CALH GrAlm SPS CALH.GrAlm 2.4.3

Inverter #1 Other HI + 34 1 Normal Alarm CALH GrWrn SPS CALH.GrWrn 2.4.3 Warning

. Inverter #2 . . . Inverter . Normal #i-1 points .

Inverter #i Active Power HI + ihbi(i) 1 Normal Alarm MMXU TotW.range MV MMXU1.TotW.range 2.4.3 Output is Too High Inverter #i Active Power HI + ihbi(i) + 1 1 Normal Alarm MMXU TotW.range MV MMXU1.TotW.range 2.4.3 Output is Too Low Inverter #i Reactive HI + ihbi(i) + 2 Power Output is Too 1 Normal Alarm MMXU TotVAr.range MV MMXU1.TotVAr.range 2.4.3 High Inverter #i Reactive HI + ihbi(i) + 3 Power Output is Too 1 Normal Alarm MMXU TotVAr.range MV MMXU1.TotVAr.range 2.4.3 Low Inverter #i current HI + ihbi(i) + 4 Output Frequency is 1 Normal Alarm MMXU Hz.range MV MMXU1.Hz.range 2.4.3 Too High Inverter #i current HI + ihbi(i) + 5 Output Frequency is 1 Normal Alarm MMXU Hz.range MV MMXU1.Hz.range 2.4.3 Too Low Inverter #i DC Input HI + ihbi(i) + 6 1 Normal Alarm MMDC Watt.range MV MMDC1.Watt.range 2.4.3 Power is Too High Inverter #i DC Input HI + ihbi(i) + 7 1 Normal Alarm MMDC Watt.range MV MMDC1.Watt.range 2.4.3 Power is Too Low Inverter #i DC Current HI + ihbi(i) + 8 1 Normal Alarm MMDC Amp.range MV MMDC1.Amp.range 2.4.3 Level is Too High

Page 41 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Inverter #i DC Current HI + ihbi(i) + 9 1 Normal Alarm MMDC Amp.range MV MMDC1.Amp.range 2.4.3 Level is Too Low Inverter #i DC Input HI + ihbi(i) + 10 1 Normal Alarm MMDC Vol.range MV MMDC1.Vol.range 2.4.3 Voltage is Too High Inverter #i DC Input HI + ihbi(i) + 11 1 Normal Alarm MMDC Vol.range MV MMDC1.Vol.range 2.4.3 Voltage is Too Low Overexcited Underexcited Inverter #i DNP3 Power (producing (absorbing HI + ihbi(i) + 12 1 DSTO PFExtSet SPG DSTO.PFExtSet 2.7 Factor Excitation VARs - VARs - Q1/Q2) Q3/Q4) Inverter #i HI + ihbi(i) + 13 1 Normal Alarm LCCH ChLiv SPS LCCH.ChLiv 2.4.3 Communication Error Inverter #i Is In Local DEROpSt.disconnected DSTO.DEROpSt.disconnected and in HI + ihbi(i) + 14 1 Normal Alarm DSTO ENS 2.10.1 Control Mode and in maintenance maintenance Inverter #i Is DC HI + ihbi(i) + 15 1 Normal Alarm DINV InvSwiAlm SPS DINV.InvSwiAlm 2.4.3 Contactor Closed Inverter #i Ground Fault HI + ihbi(i) + 16 1 Normal Alarm PDIS Str ACD PDIS.Str 2.4.3 Alarm Inverter #i DC Over HI + ihbi(i) + 17 1 Normal Alarm MMDC Vol.range MV MMDC.Vol.range 2.4.3 Voltage Alarm Inverter #i DC Under HI + ihbi(i) + 18 1 Normal Alarm MMDC Vol.range MV MMDC.Vol.range 2.4.3 Voltage Alarm Inverter #i AC HI + ihbi(i) + 19 1 Normal Alarm DINV InvACLosAlm SPS DINV.InvACLosAlm 2.4.4 Disconnect Warning Inverter #i DC HI + ihbi(i) + 20 1 Normal Alarm DINV InvDCLosAlm SPS DINV.InvDCLosAlm 2.4.4 Disconnect Warning Inverter does Inverter #i Grid not detect HI + ihbi(i) + 21 1 Normal DINV InvGriLosAlm SPS DINV.InvGriLosAlm 2.4.4 Disconnect Warning power on the grid Inverter #i Cabinet HI + ihbi(i) + 22 1 Normal Alarm SPSE GteSt.open ENS SPSE.GteSt.open 2.4.3 Open Warning

Page 42 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Inverter #i Manual HI + ihbi(i) + 23 1 Normal Alarm DINV InvManStopSt SPS DINV.InvManStopSt 2.4.3 Shutdown Warning Inverter #i Over HI + ihbi(i) + 24 1 Normal Alarm DINV EnclTmp.range MV DINV.EnclTmp.range 2.4.3 Temperature Alarm Inverter #i Under HI + ihbi(i) + 25 1 Normal Alarm DINV EnclTmp.range MV DINV.EnclTmp.range 2.4.3 Temperature Alarm Inverter #i Over HI + ihbi(i) + 26 1 Normal Alarm MMXU Hz.range MV MMXU1.Hz.range 2.4.3 Frequency Alarm Inverter #i Under HI + ihbi(i) + 27 1 Normal Alarm MMXU Hz.range MV MMXU1.Hz.range 2.4.3 Frequency Alarm Inverter #i AC Over HI + ihbi(i) + 28 1 Normal Alarm MMXU PhV.PhsA.range WYE MMXU.PhV.PhsA.range 2.4.3 Voltage Alarm Inverter #i AC Under HI + ihbi(i) + 29 1 Normal Alarm MMXU PhV.PhsA.range WYE MMXU.PhV.PhsA.range 2.4.3 Voltage Alarm Inverter #i Blown String HI + ihbi(i) + 30 1 Normal Alarm XFUS FuSt SPS XFUS.FuSt 2.4.3 Fuse Alarm Inverter #i Memory Loss HI + ihbi(i) + 31 1 Normal Alarm #SAlarMML .#SAlarMML 2.4.3 Alarm Inverter #i Hardware HI + ihbi(i) + 32 1 Normal Alarm DINV TestRsl SPS DINV.TestRsl 2.4.3 Test Failure

HI + ihbi(i) + 33 Inverter #i Other Alarm 1 Normal Alarm CALH GrAlm SPS CALH.GrAlm 2.4.3

Inverter #i Other HI + ihbi(i) + 34 1 Normal Alarm CALH GrWrn SPS CALH.GrWrn 2.4.3 Warning Battery Historian Binary Inputs Battery Bank #1 Status Dis- HB 3 Connected DBAT BatSt.connected SPC DBAT.BatSt.connected 2.4.4 of Storage connected Battery Bank #1 HB + 1 1 Normal Alarm LCCH ChLiv SPS LCCH.ChLiv 2.4.3 Communication Error Battery Bank #1 Is In Not in Local In Local HB + 2 1 DBAT BatSt.local control ENS DBAT.BatSt.local control 2.10.1 Local Control Mode Control Control

Page 43 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Battery Bank #1 Is DC HB + 3 1 Not Closed Closed DBAT DCSwCls SPS DBAT.DCSwCls 2.10.1 Contactor Closed Battery Bank #1 Is HB + 4 1 Not Charging Charging DBAT ChaSt SPS DBAT.ChaSt 2.6.2 Charging Battery Bank #1 Is Not HB + 5 1 Discharging DBAT DschSt SPS DBAT.DschSt 2.6.2 Discharging Discharging Battery Bank #1 HB + 6 External Voltage is Too 1 Normal Alarm DBAT ExtVolHiAlm SPS DBAT.ExtVolHiAlm 2.4.3 High Battery Bank #1 HB + 7 External Voltage is Too 1 Normal Alarm DBAT ExtVolLoAlm SPS DBAT.ExtVolLoAlm 2.4.3 Low Battery Bank #1 Internal HB + 8 1 Normal Alarm DBAT IntnVolHiAlm SPS DBAT.IntnVolHiAlm 2.4.3 Voltage is Too High Battery Bank #1 Internal HB + 9 1 Normal Alarm DBAT IntnVolLoAlm SPS DBAT.IntnVolLoAlm 2.4.3 Voltage is Too Low Battery Bank #1 Over HB + 10 1 Normal Alarm DBAT ExtTmpHiAlm SPS DBAT.ExtTmpHiAlm 2.4.3 Temperature Alarm Battery Bank #1 Under HB + 11 1 Normal Alarm DBAT ExtTmpLoAlm SPS DBAT.ExtTmpLoAlm 2.4.3 Temperature Alarm Battery Bank #1 HB + 12 Temperature Imbalance 1 Normal Alarm DBAT UnbTmpAlm SPS DBAT.UnbTmpAlm 2.4.3 Alarm Battery Bank #1 Over HB + 13 1 Normal Alarm DBAT ExtTmpHiWrn SPS DBAT.ExtTmpHiWrn 2.4.3 Temperature Warning Battery Bank #1 Under HB + 14 1 Normal Alarm DBAT ExtTmpLoWrn SPS DBAT.ExtTmpLoWrn 2.4.3 Temperature Warning Battery Bank #1 HB + 15 Temperature Imbalance 1 Normal Alarm DBAT UnbTmpWrn SPS DBAT.UnbTmpWrn 2.4.3 Warning Battery Bank #1 Over HB + 16 1 Normal Alarm DBAT ChaAmpHiAlm SPS DBAT.ChaAmpHiAlm 2.4.3 Charge Current Alarm

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Battery Bank #1 Over HB + 17 Discharge Current 1 Normal Alarm DBAT DschAmpHiAlm SPS DBAT.DschAmpHiAlm 2.4.3 Alarm Battery Bank #1 Over HB + 18 Charge Current 1 Normal Alarm DBAT ChaAmpHiWrn SPS DBAT.ChaAmpHiWrn 2.4.3 Warning Battery Bank #1 Over HB + 19 Discharge Current 1 Normal Alarm DBAT DschAmpHiWrn SPS DBAT.DschAmpHiWrn 2.4.3 Warning Battery Bank #1 Voltage HB + 20 1 Normal Alarm DBAT UnbVolWrn SPS DBAT.UnbVolWrn 2.4.3 Imbalance Warning Battery Bank #1 Current HB + 21 1 Normal Alarm DBAT UnbAmpWrn SPS DBAT.UnbAmpWrn 2.4.3 Imbalance Warning Battery Bank #1 Over HB + 22 1 Normal Alarm DBAT IntnVolHiAlm SPS DBAT.IntnVolHiAlm 2.4.3 Voltage Alarm Battery Bank #1 Under HB + 23 1 Normal Alarm DBAT IntnVolLoAlm SPS DBAT.IntnVolLoAlm 2.4.3 Voltage Alarm Battery Bank #1 Over HB + 24 1 Normal Alarm DBAT IntnVolHiWrn SPS DBAT.IntnVolHiWrn 2.4.3 Voltage Warning Battery Bank #1 Under HB + 25 1 Normal Alarm DBAT IntnVolLoWrn SPS DBAT.IntnVolLoWrn 2.4.3 Voltage Warning Battery Bank #1 Over HB + 26 State of Charge 1 Normal Alarm DBAT SocHiAlm SPS DBAT.SocHiAlm 2.4.3 Maximum Alarm Battery Bank #1 Under HB + 27 State of Charge 1 Normal Alarm DBAT SocLoAlm SPS DBAT.SocLoAlm 2.4.3 Minimum Alarm Battery Bank #1 Over HB + 28 State of Charge 1 Normal Alarm DBAT SocHiWrn SPS DBAT.SocHiWrn 2.4.3 Maximum Warning Battery Bank #1 Under HB + 29 State of Charge 1 Normal Alarm DBAT SocLoWrn SPS DBAT.SocLoWrn 2.4.3 Minimum Warning

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Battery Bank #1 HB + 30 1 Normal Alarm SBAT -- SPS -- 2.4.3 Contactor Failure Battery Bank #1 Fan HB + 31 1 Normal Alarm SBAT -- SPS -- 2.4.3 Error Battery Bank #1 Ground HB + 32 1 Normal Alarm SBAT -- SPS -- 2.4.3 Fault Battery Bank #1 Door HB + 33 1 Normal Alarm SBAT -- SPS -- 2.4.3 Open Alarm Battery Bank #1 HB + 34 1 Normal Alarm SBAT -- SPS -- 2.4.3 Configuration Error Battery Bank #1 HB + 35 1 Normal Alarm SBAT -- SPS -- 2.4.3 Configuration Warning Battery Bank #1 Other HB + 36 1 Normal Alarm SBAT -- SPS -- 2.4.3 Alarm Battery Bank #1 Other HB + 37 1 Normal Alarm SBAT -- SPS -- 2.4.3 Warning Battery Bank #1 Fire HB + 38 1 Normal Alarm SBAT -- SPS -- 2.4.3 Alarm Battery Bank #1 Fire HB + 39 1 Normal Alarm SBAT -- SPS -- 2.4.3 Supervisory Warning Battery Bank #1 Fire HB + 40 1 Normal Alarm SBAT -- SPS -- 2.4.3 Trouble Warning Battery Bank #1 Fire HB + 41 1 Normal Alarm SBAT -- SPS -- 2.4.3 Power Fault Warning Battery Bank #1 Chiller HB + 42 1 Normal Alarm SBAT -- SPS -- 2.4.3 Alarm Battery Bank #1 Chiller HB + 43 1 Normal Alarm SBAT -- SPS -- 2.4.3 Warning Battery Bank #1 Air HB + 44 1 Normal Alarm SBAT -- SPS -- 2.4.3 Handler Alarm

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Battery Bank #1 Air HB + 45 1 Normal Alarm SBAT -- SPS -- 2.4.3 Handler Warning Battery Bank #1 Fluid HB + 46 1 Normal Alarm SBAT -- SPS -- 2.4.3 Alarm Battery Bank #1 Fluid HB + 47 1 Normal Alarm SBAT -- SPS -- 2.4.3 Warning Battery Bank #1 Gas HB + 48 1 Normal Alarm SBAT -- SPS -- 2.4.3 Alarm Battery Bank #1 Gas HB + 49 1 Normal Alarm SBAT -- SPS -- 2.4.3 Warning Battery Bank #1 HB + 50 1 Normal Alarm SBAT -- SPS -- 2.4.3 Electrolyte Alarm Battery Bank #1 HB + 51 1 Normal Alarm SBAT -- SPS -- 2.4.3 Electrolyte Warning Battery Bank #1 HB + 52 1 Normal Alarm SBAT -- SPS -- 2.4.3 Electrical Alarm Battery Bank #1 HB + 53 1 Normal Alarm SBAT -- SPS -- 2.4.3 Electrical Warning

. Battery Bank #2 . . . . Battery Bank #b-1 . points .

Battery Bank #b Status DBAT BatSt.connected SPC DBAT.BatSt.connected HB + bhbi(b) 3 Off On 2.4.4 of Storage Battery Bank #b LCCH ChLiv SPS LCCH.ChLiv HB + bhbi(b) + 1 1 Normal Alarm 2.4.3 Communication Error Battery Bank #b Is In Not in Local In Local DBAT BatSt.local control ENS DBAT.BatSt.local control HB + bhbi(b) + 2 1 2.10.1 Local Control Mode Control Control Battery Bank #b Is DC HB + bhbi(b) + 3 1 Not Closed Closed DBAT DCSwCls SPS DBAT.DCSwCls 2.10.1 Contactor Closed Battery Bank #b Is HB + bhbi(b) + 4 1 Not Charging Charging DBAT ChaSt SPS DBAT.ChaSt 2.6.2 Charging

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class Battery Bank #b Is Not HB + bhbi(b) + 5 1 Discharging DBAT DschSt SPS DBAT.DschSt 2.6.2 Discharging Discharging Battery Bank #b HB + bhbi(b) + 6 External Voltage is Too 1 Normal Alarm DBAT ExtVolHiAlm SPS DBAT.ExtVolHiAlm 2.4.3 High Battery Bank #b HB + bhbi(b) + 7 External Voltage is Too 1 Normal Alarm DBAT ExtVolLoAlm SPS DBAT.ExtVolLoAlm 2.4.3 Low Battery Bank #b Internal HB + bhbi(b) + 8 1 Normal Alarm DBAT IntnVolHiAlm SPS DBAT.IntnVolHiAlm 2.4.3 Voltage is Too High Battery Bank #b Internal HB + bhbi(b) + 9 1 Normal Alarm DBAT IntnVolLoAlm SPS DBAT.IntnVolLoAlm 2.4.3 Voltage is Too Low HB + bhbi(b) + 10 Battery Bank #b Over 1 Normal Alarm DBAT ExtTmpHiAlm SPS DBAT.ExtTmpHiAlm 2.4.3 Temperature Alarm HB + bhbi(b) + 11 Battery Bank #b Under 1 Normal Alarm DBAT ExtTmpLoAlm SPS DBAT.ExtTmpLoAlm 2.4.3 Temperature Alarm HB + bhbi(b) + 12 Battery Bank #1 Temperature Imbalance 1 Normal Alarm DBAT UnbTmpAlm SPS DBAT.UnbTmpAlm 2.4.3 Alarm HB + bhbi(b) + 13 Battery Bank #b Over 1 Normal Alarm DBAT ExtTmpHiWrn SPS DBAT.ExtTmpHiWrn 2.4.3 Temperature Warning HB + bhbi(b) + 14 Battery Bank #b Under 1 Normal Alarm DBAT ExtTmpLoWrn SPS DBAT.ExtTmpLoWrn 2.4.3 Temperature Warning HB + bhbi(b) + 15 Battery Bank #1 Temperature Imbalance 1 Normal Alarm DBAT UnbTmpWrn SPS DBAT.UnbTmpWrn 2.4.3 Warning HB + bhbi(b) + 16 Battery Bank #b Over 1 Normal Alarm DBAT ChaAmpHiAlm SPS DBAT.ChaAmpHiAlm 2.4.3 Charge Current Alarm HB + bhbi(b) + 17 Battery Bank #b Over Discharge Current 1 Normal Alarm DBAT DschAmpHiAlm SPS DBAT.DschAmpHiAlm 2.4.3 Alarm

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class HB + bhbi(b) + 18 Battery Bank #b Over Charge Current 1 Normal Alarm DBAT ChaAmpHiWrn SPS DBAT.ChaAmpHiWrn 2.4.3 Warning HB + bhbi(b) + 19 Battery Bank #b Over Discharge Current 1 Normal Alarm DBAT DschAmpHiWrn SPS DBAT.DschAmpHiWrn 2.4.3 Warning HB + bhbi(b) + 20 Battery Bank #b Voltage 1 Normal Alarm DBAT UnbVolWrn SPS DBAT.UnbVolWrn 2.4.3 Imbalance Warning HB + bhbi(b) + 21 Battery Bank #b Current 1 Normal Alarm DBAT UnbAmpWrn SPS DBAT.UnbAmpWrn 2.4.3 Imbalance Warning HB + bhbi(b) + 22 Battery Bank #b Over 1 Normal Alarm DBAT IntnVolHiAlm SPS DBAT.IntnVolHiAlm 2.4.3 Voltage Alarm HB + bhbi(b) + 23 Battery Bank #b Under 1 Normal Alarm DBAT IntnVolLoAlm SPS DBAT.IntnVolLoAlm 2.4.3 Voltage Alarm HB + bhbi(b) + 24 Battery Bank #b Over 1 Normal Alarm DBAT IntnVolHiWrn SPS DBAT.IntnVolHiWrn 2.4.3 Voltage Warning HB + bhbi(b) + 25 Battery Bank #b Under 1 Normal Alarm DBAT IntnVolLoWrn SPS DBAT.IntnVolLoWrn 2.4.3 Voltage Warning HB + bhbi(b) + 26 Battery Bank #1 Over State of Charge 1 Normal Alarm DBAT SocHiAlm SPS DBAT.SocHiAlm 2.4.3 Maximum Alarm HB + bhbi(b) + 27 Battery Bank #1 Under State of Charge 1 Normal Alarm DBAT SocLoAlm SPS DBAT.SocLoAlm 2.4.3 Minimum Alarm HB + bhbi(b) + 28 Battery Bank #1 Over State of Charge 1 Normal Alarm DBAT SocHiWrn SPS DBAT.SocHiWrn 2.4.3 Maximum Warning HB + bhbi(b) + 29 Battery Bank #1 Under State of Charge 1 Normal Alarm DBAT SocLoWrn SPS DBAT.SocLoWrn 2.4.3 Minimum Warning HB + bhbi(b) + 30 Battery Bank #b 1 Normal Alarm SBAT -- SPS -- 2.4.3 Contactor Failure

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class HB + bhbi(b) + 31 Battery Bank #b Fan 1 Normal Alarm SBAT -- SPS -- 2.4.3 Error HB + bhbi(b) + 32 Battery Bank #b Ground 1 Normal Alarm SBAT -- SPS -- 2.4.3 Fault HB + bhbi(b) + 33 Battery Bank #b Door 1 Normal Alarm SBAT -- SPS -- 2.4.3 Open Alarm HB + bhbi(b) + 34 Battery Bank #b 1 Normal Alarm SBAT -- SPS -- 2.4.3 Configuration Error HB + bhbi(b) + 35 Battery Bank #b 1 Normal Alarm SBAT -- SPS -- 2.4.3 Configuration Warning HB + bhbi(b) + 36 Battery Bank #b Other 1 Normal Alarm SBAT -- SPS -- 2.4.3 Alarm HB + bhbi(b) + 37 Battery Bank #b Other 1 Normal Alarm SBAT -- SPS -- 2.4.3 Warning HB + bhbi(b) + 38 Battery Bank #b Fire 1 Normal Alarm SBAT -- SPS -- 2.4.3 Alarm HB + bhbi(b) + 39 Battery Bank #b Fire 1 Normal Alarm SBAT -- SPS -- 2.4.3 Supervisory Warning HB + bhbi(b) + 40 Battery Bank #b Fire 1 Normal Alarm SBAT -- SPS -- 2.4.3 Trouble Warning HB + bhbi(b) + 41 Battery Bank #b Fire 1 Normal Alarm SBAT -- SPS -- 2.4.3 Power Fault Warning HB + bhbi(b) + 42 Battery Bank #b Chiller 1 Normal Alarm SBAT -- SPS -- 2.4.3 Alarm HB + bhbi(b) + 43 Battery Bank #b Chiller 1 Normal Alarm SBAT -- SPS -- Warning 2.4.3 HB + bhbi(b) + 44 Battery Bank #b Air 1 Normal Alarm SBAT -- SPS -- Handler Alarm 2.4.3 HB + bhbi(b) + 45 Battery Bank #b Air 1 Normal Alarm SBAT -- SPS -- Handler Warning 2.4.3

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Defau Name for Name for IEC 61850 Point lt Refer Name / Description State when State when Index Event LN To value is 0 value is 1 Data Object CDC Unique String Class Class HB + bhbi(b) + 46 Battery Bank #b Fluid 1 Normal Alarm SBAT -- SPS -- Alarm 2.4.3 HB + bhbi(b) + 47 Battery Bank #b Fluid 1 Normal Alarm SBAT -- SPS -- Warning 2.4.3 HB + bhbi(b) + 48 Battery Bank #b Gas 1 Normal Alarm SBAT -- SPS -- Alarm 2.4.3 HB + bhbi(b) + 49 Battery Bank #b Gas 1 Normal Alarm SBAT -- SPS -- Warning 2.4.3 HB + bhbi(b) + 50 Battery Bank #b 1 Normal Alarm SBAT -- SPS -- Electrolyte Alarm 2.4.3 HB + bhbi(b) + 51 Battery Bank #b 1 Normal Alarm SBAT -- SPS -- Electrolyte Warning 2.4.3 HB + bhbi(b) + 52 Battery Bank #b 1 Normal Alarm SBAT -- SPS -- 2.4.3 Electrical Alarm HB + bhbi(b) + 53 Battery Bank #b 1 Normal Alarm SBAT -- SPS -- 2.4.3 Electrical Warning Vendor Specific Points

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Table 10 – Binary Input Protocol Options 3.1 SINGLE-BIT BINARY INPUTS Static (Steady-State) Group Number: 1 Capabilities Event Group Number: 2

3.1.1 Static Variation reported when variation 0 requested or in response to Class  Variation 1 – Single-bit Packed format polls:  Variation 2 – Single-bit with flag  Based on point Index (add column to table in part 5)

3.1.2 Event Variation reported when variation 0 requested or in response to Class  Variation 1 – without time polls:  Variation 2 – with absolute time Note: The support for binary input events can be determined remotely using  Variation 3 – with relative time protocol object Group 0 Variation 237 if Device Attribute Objects are supported.  Based on point Index (add column to table in part 5)

3.1.3 Event reporting mode:  Only most recent When responding with event data and more than one event has occurred for a  All events data point, an Outstation may include all events or only the most recent event. All  Based on point Index (add column to table in part 5) events must be checked to be compliant.

3.1.4 Binary Inputs included in Class 0 response:  Always  Never  Only if the point is assigned to a class  Based on point Index (add column to table in part 5)

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2.2.6 Binary Outputs Table 12 lists the binary output points to be used in the DNP3 Profile for DERs. Table 13 specifies the options to be used by outstations when reporting these points. Most of these binary output points have corresponding binary input points to provide feedback to the master that the operation is completed. In addition to this feedback, it is recommended that the master and outstation use binary output event objects. However, it must be possible for the outstation to disable this capability because it is beyond a DNP3-L2 implementation, as discussed in 1.2. Table 11 illustrates in the standard DNP Device profile format the control operations that shall be supported for every binary output point (these columns are not shown in Table 12 because of lack of space and because they are the same for all binary output points.) Although all operation pairs (Pulse, Latch, Trip/Close) are permitted, the outstation shall behave as if all points were Latched. Pulse time values in the Control Relay Output Block objects shall be ignored by the outstation. Note that all objects require select-before-operate functionality. Table 11 – Control Operations Supported

Supported Control Operations

No Ack No

–

Trip

Pulse On Pulse On Latch

Pulse Off Pulse Off Latch

Count > 1 > Count

Direct Operate Operate Direct

Select/Operate

Direct Operate Operate Direct

Cancel Current Operation Current Cancel

X X X X X X X X X

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Table 12 – Binary Output Points List IEC 61850 Default Default Name for Name for Point Cmd Event Refer Name / Description State when State when Index Class Class LN to value is 0 value is 1 Data Object CDC Unique String (option) (option) Class

System Binary Outputs DSTO DEROpSt.di ENS DSTO.DEROpSt.dis Do Not BO0 System Set Lockout State Lock Out 2 2 sconnected connected and 2.10.2 Lock Out and blocked blocked System Initiate Start-up Sequence (Return to Service) Setting this to 1 does the following: • Sets BI "System Is Starting" to 1 indicating that the system is starting up. Additional start-up status can be found in AI "System Start-up Status". Do not Initiate BO1 • Instructs all batteries to connect. Initiate 2 2 DCTE RtnSrvReq SPC DCTE.RtnSrvReq 2.4.5 Start-up • Once each battery has reported that it has Start-up connect successfully, instructs corresponding DER Unit to start. System can be shut down by executing B0 "Emergency Stop" command. This operation is the same as California Rule 21 "Soft Start". System Execute Stop (Cease to Energize) Setting this to 1 does the following: - Sets BI "System Is Emergency Stopping" to 1 indicating that an emergency stop is in progress. - Ensures that any executing operating modes Stop CeaEngz- BO2 are shut down (disabled) No Change (Emerg- 2 2 DCTE SPC DCTE.CeaEngzReq 2.4.5 Req - Ensures that any executing schedules are ency) shut down (disabled). - Instructs all inverters to shut down - Instructs all batteries to disconnect. System can be started again by executing BO "Initiate Start-up Sequence" command.

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IEC 61850 Default Default Name for Name for Point Cmd Event Refer Name / Description State when State when Index Class Class LN to value is 0 value is 1 Data Object CDC Unique String (option) (option) Class

Start Start BO3 System Permission to Start Permission Permission 2 2 DSTO PrmConn SPC DSTO.PrmConn 2.4.5 not Granted Granted Stop Stop BO4 System Permission to Stop Permission Permission 2 2 DSTO PrmDscon SPC DSTO.PrmDscon 2.4.5 not Granted Granted Open Close BO5 DER Connect/Disconnect Switch 2 2 CSWI Pos DPC CSWI. Pos 2.4.4 Switch Switch Islanded Mode. Determines how the DER behaves when in an Islanded configuration. <0> Isochronous Mode. DER attempts to control voltage and frequency independent of configured curves and Isochron- Droop BO6 settings up to the limits of the machine's 2 2 DGEN IsldCtlFol SPG DGEN.IsldCtlFol 2.11 ous Mode Mode capabilities in order to achieve AO reference voltage and AO nominal frequency. <1> Droop Mode. DER acts as a follower using Volt/VAR and Freq/Watt curves. Enable Sensed Grid Config Detection. If Enabled, the DER may independently change its Active Settings Group based on locally No observed grid conditions. Autonomou BO7 Autonomou 2 2 DECP ECPIsld ENG DECP.ECPIsld 2.11 <0> No Autonomous Detection. s Detection s Detection <1> Autonomous Detection. Inverter's Active Settings Group may differ from the Requested Settings Group Storage Capacity Units. Determines whether Amp-hrs BO8 the energy storage values are expressed in Watt-hrs 2 2 DSTO AGra ASG DSTO.AGra 2.6.2 (default) Amp-hrs or Watt-hrs. Time Constant Mode. Indicates whether Time Open Loop BO9 Constant Ramp parameters are interpreted as Response 3Tau Value 2 2 DSTO OpnLoopTau SPG DSTO.OpnLoopTau 2.3.4 Open Loop Response times or 3Tau values. Time

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Power Factor Excitation When Discharging / Producing Absorbing BO10 2 2 DFPF PFGnExtSet SPG DFPF.PFGnExtSet 2.7 Generating VARs - Q1 VARs - Q4 Producing Absorbing PFLodExtSe BO11 Power Factor Excitation When Charging 2 2 DFPF SPG DFPF.PFLodExtSet 2.7 VARs – Q2 VARs – Q3 t BO12 Enable Low/High Voltage Ride-Through Mode Disable Enable 2 2 DHVT ModEna SPC DHVT.ModEna 2.3.1 Enable Low/High Frequency Ride-Through BO13 Disable Enable 2 2 DHFT ModEna SPC DHFT.ModEna 2.3.1 Mode Enable Dynamic Reactive Current Support BO14 Disable Enable 2 2 DRGS ModEna SPC DRGS.ModEna 2.3.1 Mode BO15 Enable Dynamic Volt-Watt Mode Disable Enable 2 2 DVWD ModEna SPC DVWD.ModEna 2.3.1 BO16 Enable Frequency-Watt Mode Disable Enable 2 2 DHFW ModEna SPC DHFW.ModEna 2.3.1 BO17 Enable Active Power Limit Mode Disable Enable 2 2 DWLM ModEna SPC DWLM.ModEna 2.3.1 BO18 Enable Charge/Discharge Mode Disable Enable 2 2 DWGC ModEna SPC DWGC.ModEna 2.3.1 BO19 Enable Coordinated Charge/Discharge Mode Disable Enable 2 2 DTCD ModEna SPC DTCD.ModEna 2.3.1 BO20 Enable Active Power Response Mode #1 Disable Enable 2 2 DPKP ModEna SPC DPKP.ModEna 2.3.1 BO21 Ena ble Active Power Response Mode #2 Disable Enable 2 2 DGFL ModEna SPC DGFL.ModEna 2.3.1 BO22 Enable Active Power Response Mode #3 Disable Enable 2 2 DLFL ModEna SPC DLFL.ModEna 2.3.1 BO23 Enable Automatic Generation Control Mode Disable Enable 2 2 DAGC ModEna SPC DAGC.ModEna 2.3.1 BO24 Enable Active Power Smoothing Mode Disable Enable 2 2 DWSM ModEna SPC DWSM.ModEna 2.3.1 BO25 Enable Volt-Watt Mode Disable Enable 2 2 DVWC ModEna SPC DVWC.ModEna 2.3.1

BO26 Enable Frequency-Watt Curve Mode Disable Enable 2 2 DHFW ModEna SPC DHFW.ModEna 2.3.1 BO27 Enable Constant VArs Mode Disable Enable 2 2 DVAR ModEna SPC DVAR.ModEna 2.3.1 BO28 Enable Fixed Power Factor Mode Disable Enable 2 2 DFPF ModEna SPC DFPF.ModEna 2.3.1 BO29 Enable Volt-VAR Control Mode Disable Enable 2 2 DVVC ModEna SPC DVVC.ModEna 2.3.1 BO30 Enable Watt-VAr Mode Disable Enable 2 2 DWVR ModEna SPC DWVR.ModEna 2.3.1 BO31 Enable Power Factor Correction Mode Disable Enable 2 2 DPFC ModEna SPC DPFC.ModEna 2.3.1 BO32 Enable Pricing Mode Disable Enable 2 2 DPRG ModEna SPC DPRG.ModEna 2.3.1

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Enable Event-Based Reactive Current Support BO33 Disable Enable 2 2 DRGS ArGraMod SPC DRGS.ArGraMod 2.5.4.3 Mode BO34 Frequency -Watt Mode - Use Hysteresis Disable Enable 2 2 DHFW HysEna SPG DHFW.HysEna 2.5.3 BO35 Frequency -Watt Mode - Snapshot of Power Not Active Active 2 2 DHFW SnptEna SPG DHFW.SnptEna 2.5.3 BO36 Frequency -Watt Curve Mode - Use Hysteresis Disable Enable 2 2 DLFW HysEna SPG DLFW.HysEna 2.6.8 Frequency-Watt Curve Mode - Snapshot of BO37 Not Active Active 2 2 DLFW SnptEna SPG DLFW.SnptEna 2.6.8 Power Charge/Discharge Mode - Use Ramp Rates. Indicates whether or not Charge/Discharge Use Time Use Ramp BO38 2 2 DWGC UseRmpRte SPG DWGC.UseRmpRte 2.6.2 should use specified ramp rates or time Constants Rates constants AGC Mode - Use Ramp Rates. Indicates Use Time Use Ramp BO39 whether or not charge/discharge should use 2 2 DAGC UseRmpRte SPG DAGC.UseRmpRte 2.6.5 Constants Rates specified ramp rates or time constants Volt-Watt - Use Ramp Rates and Time Use Ramp Constants. Indicates whether Volt-Watt mode Use Time Rates AND BO40 2 2 DWST UseRmpRte SPG DWST.UseRmpRte 2.7.1 should use only Time Constants, or both Time Constants Time Constants and Ramp Rates Constants

Volt-VAr Enable Autonomous Voltage BO41 Disable Enable 2 2 DVVR VRefAdjEna SPG DVVR.VRefAdjEna 2.7.3 Reference Adjustment

Schedule Binary Outputs S (S=42 for this version of the Set Selected Scheduled Ready Not Ready Ready 2 2 FSCH Mod ENC FSCHxx.Mod 2.9 specifcation) Set Selected Schedule Repeat Do Not S+1 Repeat 2 2 FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Weekly Sunday Repeat Set Selected Schedule Repeat Do Not S+2 Repeat 2 2 FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Weekly Monday Repeat

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Set Selected Schedule Repeat Do Not S+3 Repeat 2 2 FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Weekly Tuesday Repeat Set Selected Schedule Repeat Do Not S+4 Repeat 2 2 FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Weekly Wednesday Repeat Set Selected Schedule Repeat Do Not S+5 Repeat 2 2 FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Weekly Thursday Repeat Set Selected Schedule Repeat Do Not S+6 Repeat 2 2 FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Weekly Friday Repeat Set Selected Schedule Repeat Do Not S+7 Repeat 2 2 FSCH SchdReuse SPG FSCHxx.SchdReuse 2.9 Weekly Saturday Repeat Vendor Specific Points

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Table 13 – Binary Output Protocol Options

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3.3 Binary Output Status and Control Relay Output Block Binary Output Status Group Number: 10 Binary Output Event Group Number: 11 Capabilities CROB Group Number: 12 Binary Output Command Event Object Num: 13

3.3.1 Minimum pulse time allowed with Trip, Close, and Pulse On commands:  Fixed at __0__ms  Based on point Index (add column to table in part 5)

3.3.2 Maximum pulse time allowed with Trip, Close, and Pulse On commands:  Fixed at ___65535__ms  Based on point Index (add column to table in part 5)

3.3.3 Binary Output Status included in Class 0 response:  Always  Never Only if the point is assigned to a class  Based on point Index (add column to table in part 5)

3.3.4 Reports Output Command Event Objects:  Never  Only upon a successful Control  Upon all control attempts

3.3.5 Static Variation reported when variation 0 requested or in response to Class  Variation 1 – packed format polls:  Variation 2 – output status with flags  Based on point Index (add column to table in part 5)

3.3.6 Event Variation reported when variation 0 requested or in response to Class  Variation 1 – status without time polls:  Variation 2 – status with time Note: The support for binary output events can be determined remotely using protocol object Group 0 Variation 222.  Based on point Index (add column to table in part 5)

3.3.7 Command Event Variation reported when variation 0 requested or in response  Variation 1 – without time to Class polls:  Variation 2 – with absolute time

 Based on point Index (add column to table in part 5)

3.3.8 Event reporting mode:  Only most recent When responding with event data and more than one event has occurred for a data  All events point, an Outstation may include all events or only the most recent event

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3.3.9 Command event reporting mode:  Only most recent When responding with event data and more than one event has occurred for a data  All events point, an Outstation may include all events or only the most recent event

3.3.10 Maximum Time between Select and Operate  Not Applicable  Fixed at _____ seconds  Configurable, range 1 to 60 seconds  Configurable, selectable from___,___,___ seconds  Configurable, other, describe______ Variable, explain ______ Based on point Index (add column to table in part 5)

3.3.11 Binary Outputs Event Buffer Organization:  Fixed at ______When event buffers are allocated per object group (see part 1.7.6), indicate the number  Configurable, range ______to ______of events that can be buffered for Binary Outputs. If event buffers are not allocated per  Configurable, selectable from ____,____,____ object group then set “Fixed at 0”.  Configurable, other, describe______

3.3.12 Binary Output Commands Event Buffer Organization:  Fixed at ______When event buffers are allocated per object group (see part 1.7.6), indicate the number  Configurable, range ______to ______of events that can be buffered for Binary Output Commands. If event buffers are not  Configurable, selectable from ____,____,____ allocated per object group then set “Fixed at 0”.  Configurable, other, describe______

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2.2.7 Counters Table 14 lists the counter points to be used in the DNP3 Profile for DERs. Table 15 specifies the options to be used by outstations when reporting these points. The purpose of these points is to provide the master with a log of the energy transferred in and out of the DER that can be used to analyze the efficiency of the system. The values of these points are not intended to represent the output of a revenue-quality meter or to be used for billing purposes. The following rules apply to these counters: 1. The outstation shall freeze these counters periodically beginning at startup. 2. The master shall control the period of freezing using the Freeze Counter Interval analog output (AO20). The time period is in milliseconds (ms). On startup, the default period shall be 5 minutes. If the outstation supports non-volatile storage of parameters, it shall use the last period set by the master on startup. 3. All counters shall be frozen at the same moment. Although IEC 61850 defines a separate freezing period for each counter, outstations implementing this profile shall use a single value to control the freeze period of all counters. 4. The outstation shall not clear (zero) counters when it freezes them. The energy transferred in a given interval can be calculated by subtracting the counter values at the start and end of an interval. Note in Table 15 that all counter values and frozen counter values shall be timestamped. 5. The freezing period is not necessarily aligned with clock time. For instance, if a period of 5 minutes is set, the outstation may freeze the counters at 2 minutes after the hour and 7 minutes after the hour instead of 5 minutes and 10 minutes. 6. The outstation shall implement the following normal behavior of DNP3 counters: a. As noted in Table 14 and Table 15 , the outstation shall provide the following for each energy value listed: • a Static Counter with Flag object (g20v1) containing the current value of the counter at any time • a Static Frozen Counter with Flag and Time object (g21v5) containing the most recently frozen value of the counter and the time it was frozen b. The Static Counter and the Static Frozen Counter for the same energy value shall have the same point index. c. The Static Counter shall update every time the outstation counts an energy value. d. When the outstation freezes the counters, it shall copy the value in the Static Counter point into the Frozen Counter point and buffer a Frozen Counter Event with Flag and Time object (g23v5) with the same value. It shall update the timestamps on these objects with the time of freezing. e. The next time the outstation freezes the counters, it will buffer another Frozen Counter event for each point (not just update the value in the first object). In this way, the outstation will build a timestamped log of the energy values in the Frozen Counter Event buffer.

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f. At any time after the Frozen Counter Events have been buffered, the master can retrieve them (including timestamps) by reading event class 3 (assuming the master does not reassign the class of these events). g. After the master has retrieved the Frozen Counter events, it must send a confirmation to the outstation, after which the outstation will clear its buffer. It is assumed the master is responsible for the integrity of the energy log after it has sent the confirmation message. 7. The minimum size of the Frozen Counter Event buffer within the outstation is not specified by this profile. It is noted that a day’s worth of 5-minute energy intervals can be calculated as follows: (4 bytes value + 6 bytes timestamp + 1 byte flag) x 4 counters/event x 12 events/hr x 24 hrs = 12672 bytes minimum, not including any internal overhead, per day. 8. Outstations implementing this profile shall not buffer (non-frozen) Counter Event objects (g22). If the master requests these objects, the outstation shall send a DNP3 null response. 9. All the energy values shall be measured at the connection point, including the total for both generation and storage. The master selects the interval between freeze operations by setting the value in AO20 and setting the units of the interval as follows in AO21: <0> The outstation does not repeat the action, regardless of the Interval count. <1> Milliseconds - In this case the interval is always counted relative to the Start Time and is constant regardless of the clock time set at the Outstation. <2> Seconds - At the same millisecond within the second that is specified in the Start Time. <3> Minutes - At the same second and millisecond within the minute that is specified in the Start Time. <4> Hours - At the same minute, second and millisecond within the hour that is specified in the Start Time. <5> Days - At the same time of day that is specified in the Start Time. <6> Weeks - On the same day of the week at the same time of day that is specified in the Start Time <7> Months - On the same day of each month at the same time of day that is specified in the Start Time. If the Start Time falls on the 29th or greater day of the month, the outstation shall not perform the action in months that do not have such a day <8> Months on Same Day of Week from Start of Month - At the same timeof day on the same day of the week after the beginning of the month as the day specified in the Start Time. For instance, if the Start Time specifies the second Tuesday of February and the Interval Count is 2, the next action shall occur on the second Tuesday of April. In the same example, if the Interval Count is set to 12, this is the same as specifying, “Every year on the second Tuesday in February”. If the specified day does not occur in a given month when an action was scheduled to occur, the outstation shall not perform the action that month but shall perform it at the next valid scheduled time. <9> Months on Same Day of Week from End of Month - The outstation shall interpret this setting as in <8>, but the day of the week shall be measured from the end of the month, e.g.,“the second-last Tuesday in February”.

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Table 14 – Counter Points List IEC 61850 Default Default Frozen Class Class Counter Point Assigned Assigned Name / Description Exists Refer To: Index to to Frozen LN LN Data (Yes or CDC Counter Counter Class Inst Object No) Events Events

System Counters

C0 System Active Energy Delivered. Measured in watt-hours. n/a Yes 3 MMTR 1 SupWh BCR 2.4.1

C1 System Active Energy Received. Measured in watt-hours. n/a Yes 3 MMTR 1 DmdWh BCR 2.4.1 C2 System Reactive Energy Delivered. Measured in VAr-hours. n/a Yes 3 MMTR 1 SupVArh BCR 2.4.1 C3 System Reactive Energy Received. Measured in VAr-hours. n/a Yes 3 MMTR 1 DmdVArh BCR 2.4.1 Meter Historian Counters HM Meter #1 Active Energy Delivered. Measured in watt-hours. n/a Yes 3 MMTR 2 SupWh BCR 2.4.1 HM + 1 Meter #1 Active Energy Received. Measured in watt-hours. n/a Yes 3 MMTR 2 DmdWh BCR 2.4.1 HM + 2 Meter #1 Reactive Energy Delivered. Measured in VAr-hours. n/a Yes 3 MMTR 2 SupVArh BCR 2.4.1 HM + 3 Meter #1 Reactive Energy Received. Measured in VAr-hours. n/a Yes 3 MMTR 2 DmdVArh BCR 2.4.1 . . Meter #2 . . . Meter #m-1 points . HM + mhc(m) Meter #m Active Energy Delivered. Measured in watt-hours. n/a Yes 3 MMTR m+1 SupWh BCR 2.4.1

HM + mhc(m)+1 Meter #m Active Energy Received. Measured in watt-hours. n/a Yes 3 MMTR m+1 DmdWh BCR 2.4.1 Meter #m Reactive Energy Delivered. Measured in VAr- 2.4.1 HM + mhc(m)+2 n/a Yes 3 MMTR m+1 SupVArh BCR hours. Meter #m Reactive Energy Received. Measured in VAr- HM + mhc(m)+3 n/a Yes 3 MMTR m+1 DmdVArh BCR 2.4.1 hours. Vendor Specific Counters

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Table 15 – Counter Protocol Options 3.4 COUNTERS/FROZEN COUNTERS Static Counter Group Number: 20 Static Frozen Counter Group Number: 21 Capabilities Counter Event Group Number: 22 Frozen Counter Event Group Number: 23

3.4.1 Static Counter Variation reported when variation 0 requested or in response  Variation 1 – 32-bit with flag to Class polls:  Variation 2 – 16-bit with flag  Variation 5 – 32-bit without flag  Variation 6 – 16-bit without flag  Based on point Index (add column to table in part 5)

3.4.2 Counter Event Variation reported when variation 0 requested or in response  Variation 1 – 32-bit with flag to Class polls:  Variation 2 – 16-bit with flag Note: The support for counter events can be determined remotely using protocol object Group 0 Variation 227.  Variation 5 – 32-bit with flag and time  Variation 6 – 16-bit with flag and time  Based on point Index (add column to table in part 5)

3.4.3 Counters included in Class 0 response:  Always  Never  Only if the point is assigned to a class  Based on point Index (add column to table in part 5)

3.4.4 Counter Event reporting mode:  A: Only most recent (value at time of event) When responding with event data and more than one event has occurred  B: Only most recent (value at time of response) for a data point, an Outstation may include all events or only the most recent event. Only the most recent event is typically reported for  C: All events Counters. When reporting “only most recent”, the counter value reported  Based on point Index (add column to table in part 5) in the response may be the value at the time of the original event or it may be the value at the time of the response.

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3.4 COUNTERS/FROZEN COUNTERS Static Counter Group Number: 20 Static Frozen Counter Group Number: 21 Capabilities Counter Event Group Number: 22 Frozen Counter Event Group Number: 23

3.4.5 Static Frozen Counter Variation reported when variation 0 requested or in  Variation 1 – 32-bit with flag response to Class polls:  Variation 2 – 16-bit with flag  Variation 5 – 32-bit with flag and time  Variation 6 – 16-bit with flag and time  Variation 9 – 32-bit without flag  Variation 10 – 16-bit without flag  Based on point Index (add column to table in part 5)

3.4.6 Frozen Counter Event Variation reported when variation 0 requested or in  Variation 1 – 32-bit with flag response to Class polls:  Variation 2 – 16-bit with flag

 Variation 5 – 32-bit with flag and time Note: The support for frozen counter events can be determined remotely using protocol object Group 0 Variation 225.  Variation 6 – 16-bit with flag and time  Based on point Index (add column to table in part 5)

3.4.7 Frozen Counters included in Class 0 response:  Always  Never  Only if the point is assigned to a class  Based on point Index (add column to table in part 5)

3.4.8 Frozen Counter Event reporting mode:  A: Only most recent frozen value When responding with event data and more than one event has occurred for a data  B: All frozen values point, an Outstation may include all events or only the most recent event. All events are typically reported for Frozen Counters.  Based on point Index (add column to table in part 5)

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3.4 COUNTERS/FROZEN COUNTERS Static Counter Group Number: 20 Static Frozen Counter Group Number: 21 Capabilities Counter Event Group Number: 22 Frozen Counter Event Group Number: 23

3.4.9 Counters Roll Over at:  16 Bits (65,535)  32 Bits (4,294,967,295)  Other Fixed Value ______ Configurable; range ______to______ Configurable, selectable from ___,___,___  Configurable, other, describe______ Based on point Index (add column to table in part 5)

3.4.10 Counters frozen by means of:  Master Request  Freezes itself without concern for time of day  Freezes itself and requires time of day  Other, explain ______

3.4.11 Counters Event Buffer Organization:  Fixed at ______When event buffers are allocated per object group (see part 1.7.6), indicate the  Configurable, range ______to ______number of events that can be buffered for Counters. If event buffers are not allocated per object group then set “Fixed at 0”.  Configurable, se lectable from ____,____,____  Configurable, other, describe______

3.4.12 Frozen Counters Event Buffer Organization:  Fixed at ______When event buffers are allocated per object group (see part 1.7.6), indicate the  Configurable, range ______to ______number of events that can be buffered for Frozen Counters. If event buffers are not allocated per object group then set “Fixed at 0”.  Configurable, selectable from ____,____,____  Configurable, other, describe______

3.4.13 Reports counter events for change of value:  Yes for all counters Indicate if counter events are created when the counter value changes.  No for all counters  Configurable, based on point Index (add column to table in part 5)

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2.2.8 Analog Inputs Table 16 lists the analog input points to be used in the DNP3 Profile for DERs. Table 17 specifies the options to be used by outstations when reporting these points. Support for analog input event objects is required. Note that these are read/only values that represent the current state of the system. Some of these values can be changed using corresponding analog output points listed in section 2.2.9. Other points are measurement points whose values change indirectly depending on the mode of operation of the device. The point numbers for the writeable values and the read/only values are not the same. Note that support for floating point analog input objects is not required by this specification because they are not DNP3-L2 objects. However, the use of these object variations by agreement between the master and outstation is highly recommended. Floating-point quantities shall not be scaled by the outstation; they are reported in the units specified in Table 16. For instance, 1kW is reported as 1.0E+3 Watts. Regardless of whether floating point is implemented, per the rules of DNP3, any device that supports floating-point objects must also support integer analog input objects. The “Transmitted Value”, “Scaling” and “Resolution” columns apply when integers are used. The integer value is to be reported with as little scaling as possible, as specified in Table 16. Only those values typically measured in fractions of an integer (power factor, angle, etc.) shall be scaled. This means that for some systems, 32-bit analog input object variations will be required in order to transmit the data as integers without overflow; e.g. a 50kW real power output cannot be represented with a 16-bit value because it would exceed 32767 Watts. The Device Profile document for the outstation should not just copy the 32-bit minimum and maximum values shown here, but show the actual maximum and minimum values for the system. A “Resolution” column is normally shown in the Device Profile document, but because this profile cannot specify particular hardware for the outstation, the column is not included. Implementers should simply note that unless particularly specified, a 1% resolution from the nominal value is preferred. Support for frozen analog input objects is not required.

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Table 16 – Analog Input Points List Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class System Analog Inputs

AI0 DER Profile Version Number. Always 3 100 100 0.01 0 n/a 2.2.1

the number 1.00 for this specification.

AI1 DER Profile Implementation Level. 1, 2 3 1 3 1 0 n/a 2.2.1 or 3 to indicate support for Level 1, Level 2 or Level 3 respectively. AI2 Nameplate Minimum Voltage Rating 3 0 2147483647 0.1 0 Volts DGEN VMinRtg ASG 2.10.4 AI3 Nameplate Maximum Voltage Rating 3 0 2147483647 0.1 0 Volts DGEN VMaxRtg ASG 2.10.4 AI4 Nameplate Active Generation Power 3 0 2147483647 1 0 Watts DGEN WMaxRtg ASG 2.10.4 Rating at Unity Power Factor AI5 Nameplate Active Charging Power 3 -2147483648 0 1 0 Watts DSTO ChaWMaxRtg ASG 2.10.4 Rating at Unity Power Factor AI6 Nameplate Active Generation Power 3 0 2147483647 1 0 Watts DGEN WOvPFRtg ASG 2.10.4 Rating at Specified Over-Excited Power Factor AI7 Nameplate Active Charging Power 3 -2147483648 0 1 0 Watts DSTO ChaWOvPFRt ASG 2.10.4 Rating at Specified Over-Excited g Power Factor AI8 Specified Over-Excited Power Factor 3 -100 100 0.01 0 None DGEN OvPFRtg ASG 2.10.4 AI9 Nameplate Active Generation Power 3 0 2147483647 1 0 Watts DGEN WUnPFRtg ASG 2.10.4 Rating at Specified Under-Excited Power Factor AI10 Nameplate Active Charging Power 3 -2147483648 0 1 0 Watts DSTO ChaWUnPFRt ASG 2.10.4 Rating at Specified Under-Excited g Power Factor AI11 Specified Under-Excited Power Factor 3 -100 100 0.01 0 None DGEN UnPFRtg ASG 2.10.4 AI12 Nameplate Reactive Supply (Injection) 3 0 2147483647 1 0 VARs DGEN IvarMaxRtg ASG 2.10.4 Power Rating AI13 Nameplate Reactive Absorption Power 3 -2147483648 0 1 0 VARs DGEN AvarMaxRtg ASG 2.10.4 Rating AI14 Nameplate Apparent Generation 3 0 2147483647 1 0 VAs DGEN VAMaxRtg ASG 2.10.4 Power Rating AI15 Nameplate Apparent Charging Power 3 -2147483648 0 1 0 VAs DSTO ChaVAMaxRtg ASG 2.10.4 Rating AI16 Nameplate Storage Actual Energy 3 0 2147483647 1 0 Amp-hrs DSTO WhRtg ASG 2.6.2

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class Capacity. Nameplate (original) actual or Watt- total energy capacity of the storage hrs system expressed in Storage Capacity Units. AI17 Storage Effective Actual Energy 3 0 2147483647 1 0 Amp-hrs DSTO EffWh ASG 2.6.2 Capacity. Present actual total energy or Watt- capacity of the storage system hrs expressed in Storage Capacity Units. AI18 Storage Usable Energy Capacity. 3 0 2147483647 1 0 Amp-hrs DSTO UseWh ASG 2.6.2 Usable energy capacity of the storage or Watt- system expressed in Storage Capacity hrs Units. AI19 Nameplate AC Current Maximum 3 0 2147483647 0.1 0 Amps DGEN AMaxRtg ASG 2.10.4 Generation Rating AI20 Nameplate AC Current Maximum 3 -2147483648 0 0.1 0 Amps DSTO ChaAMaxRtg ASG 2.10.4 Charging Rating AI21 Remaining Reactive Susceptance 3 -2147483648 2147483647 1 0 Sie- DGEN SuscRtg ASG 2.10.4 mens AI22 IEEE 1547 Normal Operating 3 0 2 1 0 None -- -- 2.10.4 Performance Category. Enumeration: (list) <0> unknown <1> Category A <2> Category B AI23 IEEE 1547 Abnormal Operating 3 0 3 1 0 None -- -- 2.10.4 Performance Category. Enumeration: (list) <0> unknown <1> Category I <2> Category II <3> Category III AI24 Number of System Schedules 3 0 Varies. May 1 0 None -- -- 2.2.1 not be r/w AI25 Number of Meters 3 0 Varies. May 1 0 None -- -- 2.2.1 not be r/w AI26 Number of Inverters 3 0 Varies. May 1 0 None -- -- 2.2.1 not be r/w AI27 Number of Batteries 3 0 Varies. May 1 0 None -- -- 2.2.1 not be r/w

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI28 Number of DER units connected to 3 0 Varies. May 1 0 None DSTO InclDER ORG 2.2.1 controller not be r/w AI29 Reference Voltage 2 0 2147483647 0.1 0 Volts DECP VRef ASG 2.10.4 AI30 Reference Voltage Offset 2 -2147483648 2147483647 0.1 0 Volts DECP VRefOfs ASG 2.10.4 AI31 Nominal Grid Frequency 2 0 70000 0.001 0 Hz DECP EcpNomHz ASG 2.10.4 AI32 Maximum Active Generation Power 2 0 2147483647 1 0 Watts DGEN WMax ASG 2.6.2 AI33 Maximum Active Charging Power 2 -2147483648 0 1 0 Watts DSTO ChaWMax ASG 2.6.2 AI34 Maximum Reactive Injection Power 2 0 2147483647 1 0 VARs DGEN IvarMax ASG 2.7 AI35 Maximum Reactive Absorption Power 2 -2147483648 0 1 0 VARs DGEN AvarMax ASG 2.7 AI36 Maximum Apparent Generation Power 2 0 2147483647 1 0 VA DGEN VAMax ASG 2.6.2 AI37 Maximum Apparent Charging Power 2 -2147483648 0 1 0 VA DSTO ChaVAMax ASG 2.6.2 AI38 Minimum Voltage 2 0 2147483647 0.1 0 Volts DECP VMin ASG 2.10.4 AI39 Maximum Voltage 2 0 2147483647 0.1 0 Volts DECP VMax ASG 2.10.4 AI40 Open Loop Response Time 2 0 1000 0.1 0 % DGEN OpnLoopPct ASG 2.3.4 Percentage. Percent of target to reach within the open loop response time. Default is 90%. AI41 Power Factor Sign Convention: 2 1 2 1 0 None MMXU PFSign ENG 2.7 <1> IEC – active power <2> IEEE – lead/lag AI42 Reference for Reactive Power 2 0 3 1 0 None DGEN VArSetRef ENG 2.7 Setpoints. Selects which setpoint is (list) active. Default is <3>. <0> Not applicable / Unknown <1> Percent of Maximum Active Power (WMax) <2> Percent of Maximum Reactive Power (VArMax) <3> Percent of Available Reactive Power (VArAvl) AI43 System Available Active Generation 2 0 2147483647 1 0 Watts MMXU TotW MV 2.10.4 Power AI44 System Available Active Charging 2 -2147483648 0 1 0 Watts MMXU TotChaW MV 2.10.4 Power AI45 System Available Reactive Injection 2 0 2147483647 1 0 VARs DGEN AvarAvl MV 2.7 Power

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI46 System Available Reactive Absorption 2 -2147483648 0 1 0 VARs DGEN IvarAvl MV 2.7 Power AI47 System Available Actual State of 2 0 1000 0.1 0 % DSTO SocPct MV 2.10.4 Charge – Currently available energy in the storage system, as a percentage of Nameplate Storage Actual Capacity. AI48 System Available Usable State of 2 0 1000 0.1 0 % DSTO UseSocPct MV 2.10.4 Charge – Currently usable energy in the storage system, as a percentage of Nameplate Storage Usable Capacity. AI49 System Start-up Status 2 -1 99 1 0 None DGEN DEROpSt ENS 2.4.5 (list) AI50 DER Start (Return to Service) Voltage 2 0 20000 0.01 0 Percent DCTE VHiLim ASG 2.4.5 High Limit. Percent of Reference Voltage. AI51 DER Start (Return to Service) Voltage 2 0 10000 0.01 0 Percent DCTE VLoLim ASG 2.4.5 Low Limit. Percent of Reference Voltage. AI52 DER Start (Return to Service) 2 0 70000 0.001 0 Hz DCTE HzHiLim ASG 2.4.5 Frequency High Limit AI53 DER Start (Return to Service) 2 0 70000 0.001 0 Hz DCTE HzLoLim ASG 2.4.5 Frequency Low Limit AI54 DER Start (Return to Service) Delay 2 0 2147483647 1 0 Sec DCTE RtnDlTmms ING 2.4.5

AI55 DER Start (Return to Service) Time 2 0 2147483647 1 0 Sec DCTE WinTms ING 2.4.5 Window AI56 DER Start (Return to Service) Ramp 2 0 2147483647 1 0 Sec DCTE RtnRmpTmms ING 2.4.5 Up Time AI57 DER Stop (Cease to Energize) Time 2 0 2147483647 1 0 Sec DCTE WinTms ING 2.4.5 Window AI58 DER Stop (Cease to Energize) Ramp 2 0 2147483647 1 0 Sec DCTE RmpTms ING 2.4.5 Down Time AI59 DER Stop (Cease to Energize) 2 0 2147483647 1 0 sec DCTE RvrtTms ING 2.4.5 Reversion Timeout Period . Time to revert from the stopped state and return to service.

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI60 Connect/Disconnect Time Window 2 0 2147483647 1 0 sec DCTE WinTms ING 2.4.4 AI61 Connect/Disconnect Reversion 2 0 2147483647 1 0 sec DCTE RvrtTms ING 2.4.4 Timeout Period . Timeout (reversion time is for the Disconnect only) AI62 Maximum Generation Ramp Up Rate. 2 0 500000 0.1 0 % per DCTE RpuRteMax ASG 2.3.4 The maximum generation ramp up rate sec expressed as a percentage of the Maximum Generation Rate (WMax) per second. AI63 Maximum Generation Ramp Down 2 0 500000 0.1 0 % per DCTE RpdRteMax ASG 2.3.4 Rate. The maximum generation ramp sec down rate expressed as a percentage of the Maximum Generation Rate (WMax) per second. AI64 Maximum Charging Ramp Up Rate. 2 0 500000 0.1 0 % per DCTE RpuChaRteMa ASG 2.3.4 The maximum charging ramp up rate sec x expressed as a percentage of the Maximum Charging Rate (WChaMax) per second. AI65 Maximum Charging Ramp Down Rate. 2 0 500000 0.1 0 % per DCTE RpdChaRteMa ASG 2.3.4 The maximum charging ramp down sec x rate expressed as a percentage of the Maximum Charnging Rate (WChaMax) per second. AI66 Requested Settings Group. 2 0 255 1 0 None DECP EcpIsldSt ENG 2.11 Enumeration: (list) <0> Not Used <1> Unspecified / Autonomously Determined (see BO Enable Sensed Grid Config Detection) <2> Factory Configuration <3> Default Configuration / Comms Lost <4> Normal Grid-Connected Configuration <5> Islanded Condition 1 (small, local island) <6> Islanded Condition 2 (larger, area island)

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class <7> Islanded Condition 3 (largest, regional island) <8> 1st Alternate Grid-Connected Configuration <9> 2nd Alternate Grid-Connected Configuration <10> 3rd Alternate Grid-Connected Configuration <11-255> Reserved for future assignment AI67 Settings Group Being Edited. 2 0 255 1 0 None DECP EcpIsldSt ENG 2.11 Enumeration: (list) <0> Not Used <1> Unspecified / Autonomously Determined (see BO Enable Sensed Grid Config Detection) <2> Factory Configuration <3> Default Configuration / Comms Lost <4> Normal Grid-Connected Configuration <5> Islanded Condition 1 (small, local island) <6> Islanded Condition 2 (larger, area island) <7> Islanded Condition 3 (largest, regional island) <8> 1st Alternate Grid-Connected Configuration <9> 2nd Alternate Grid-Connected Configuration <10> 3rd Alternate Grid-Connected Configuration <11-255> Reserved for future assignment AI68 Active Settings Group. Note this may 2 0 255 1 0 None DECP EcpIsldSt ENS 2.11 differ from the Requested Settings (list) Group or Settings Group Being Edited analog outputs depending on whether communications has been lost and

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class how the Enable Sensed Grid Config Detection binary output is set. <0> Not Used <1> Unspecified / Autonomously Determined (see BO42) <2> Factory Configuration <3> Default Configuration / Comms Lost <4> Normal Grid-Connected Configuration <5> Islanded Condition 1 (small, local island) <6> Islanded Condition 2 (larger, area island) <7> Islanded Condition 3 (largest, regional island) <8> 1st Alternate Grid-Connected Configuration <9> 2nd Alternate Grid-Connected Configuration <10> 3rd Alternate Grid-Connected Configuration <11-255> Reserved for future assignment AI69 Freeze Counter Interval. interval 2 0 2147483647 1 0 n/a 2.2.7 between freeze counter operations after the initial occurrence. A zero value means the free counter operation is not repeated. AI70 Freeze Counter Interval Units. Units of 2 0 9 1 0 None 2.2.7 the interval between freeze counter (list) operations. See reference for values.

AI71 Low/High Voltage Ride-Through Signal 2 0 2147483647 1 0 n/a DHVT EcpRef1 ORG 2.5.1 Meter ID. Referenced ECP. This is the meter from which current is being read to evaluate and provide support.

1 DHVT.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXN.Vol

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI72 Low/High Voltage Ride-Through 2 0 2147483647 0.1 0 Volts MMXN Vol MV 2.5.1 Voltage Reference Input. Active voltage measurement read from the meter and used as an input to the mode. AI73 Low/High Voltage Ride-Through High 2 0 2147483647 1 0 n/a PTOV BlkRef ORG 2.5.1 Must Trip Curve Index. Index of the Voltage Ride-through curve which specifies trip points when the voltage is high. AI74 Low/High Voltage Ride-Through Low 2 0 2147483647 1 0 n/a PTUV BlkRef ORG 2.5.1 Must Trip Curve Index. Index of the Voltage Ride-through curve which specifies trip points when the voltage is low. AI75 Low/High Voltage Ride-Through High 2 0 2147483647 1 0 n/a PTOV BlkRef ORG 2.5.1 Momentary Cessation Curve Index. Index of the Voltage Ride-through curve which specifies where generation / discharging must stop when the voltage is high. AI76 Low/High Voltage Ride-Through Low 2 0 2147483647 1 0 n/a PTUV BlkRef ORG 2.5.1 Momentary Cessation Curve Index. Index of the Voltage Ride-through curve which specifies where generation / discharging must stop when the voltage is low. AI77 Low/High Frequency Ride-Through 2 0 2147483647 1 0 n/a DHFT EcpRef2 ORG 2.5.2 Signal Meter ID. Referenced ECP. This is the meter from which current is being read to evaluate and provide support. AI78 Low/High Frequency Ride-Through 2 0 2147483647 0.1 0 Volts MMXU Hz MV 2.5.2 Frequency Reference Input. Active frequency measurement read from the meter and used as an input to the mode.

2 DHFT.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.Hz

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI79 Low/High Frequency Ride-Through 2 0 2147483647 1 0 n/a PTOF BlkRef ORG 2.5.2 High Must Trip Curve Index. Index of the Frequency Ride-through curve which specifies trip points when the frequency is high. AI80 Low/High Frequency Ride-Through 2 0 2147483647 1 0 n/a PTUF BlkRef ORG 2.5.2 Low Must Trip Curve Index. Index of the Frequency Ride-through curve which specifies trip points when the frequency is low. AI81 Low/High Frequency Ride-Through 2 0 2147483647 1 0 n/a PTOF BlkRef ORG 2.5.2 High Momentary Cessation Curve Index. Index of the Frequency Ride- through curve which specifies where generation / discharging must stop when the frequency is high. AI82 Low/High Frequency Ride-Through 2 0 2147483647 1 0 n/a PTUF BlkRef ORG 2.5.2 Low Momentary Cessation Curve Index. Index of the Frequency Ride- through curve which specifies where generation / discharging must stop when the frequencyf is low. AI83 Dynamic Reactive Current Support 2 0 number of 1 0 n/a DRGS ModPrio ING 2.10.4 Mode Priority modes AI84 Dynamic Reactive Current Support 2 0 2147483647 1 0 sec DRGS WinTms ING 2.3.2 Enabling Time Window AI85 Dynamic Reactive Current Support 2 0 2147483647 1 0 sec DRGS RmpTms ING 2.3.2 Enabling Ramp Time AI86 Dynamic Reactive Current Support 2 0 2147483647 1 0 sec DRGS RvrtTms ING 2.3.2 Timeout Period AI87 Dynamic Reactive Current Support 2 0 2147483647 1 0 n/a DRGS EcpRef3 ORG 2.5.3 Signal Meter ID. Referenced ECP. This is the meter from which current is being read to evaluate and provide support. AI88 Dynamic Reactive Current Support 2 0 2147483647 0.1 0 Volts MMXN Vol MV 2.5.3

3 DRGS.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXN.Vol

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class Voltage Reference Input. Votltage measurement read from the meter and used as an input to the mode. AI89 Dynamic Reactive Current Support 2 0 2147483647 0.1 0 Volts DRGS VAv MV 2.5.3 Moving Average Voltage AI90 Dynamic Reactive Current Support 2 -10000 10000 0.1 0 % DRGS DelV MV 2.5.3 Present Delta Voltage. Difference in Volts between the present measured Voltage and the Moving Average Voltage (RDGS.Vav) as a percentage of the reference voltage (VRef) AI91 Dynamic Reactive Current Support - 2 0 2 1 0 None DRGS ArGraMod SPG 2.5.3 Gradient Mode. Enumeration: (list) <0> Undefined <1> Gradients reach 0 at the moving average Voltage <2> Gradients reach 0 at the Voltage deadbands AI92 Dynamic Reactive Current Support 2 -10000 0 0.1 0 % DRGS DbVMin ASG 2.5.3 Deadband Minimum Voltage. Percentage of the nominal voltage (DRCT.Vref), measured from the moving average voltage (RDGS.VAv). Support is no longer applied when the voltage stays above this value for the length of the Hold Time. AI93 Dynamic Reactive Current Support 2 0 10000 0.1 0 % DRGS DbVMax ASG 2.5.3 Deadband Maximum Voltage. Percentage of the nominal voltage (DRCT.Vref), measured from the moving average voltage (RDGS.VAv). Support is no longer applied when the voltage stays below this value for the length of the Hold Time. AI94 Dynamic Reactive Current Support 2 -2147483648 2147483647 0.001 0 % DRGS ArGraSag ASG 2.5.3 Gradient for Sags. Percentage of the current rated current (DRAT.ARtg) to apply per capacitively per percentage of the percent negative deviation from the moving voltage

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class average voltage (RDGS.Av). It is a deviatio ratio of percent and is therefore n unitless. AI95 Dynamic Reactive Current Support 2 -2147483648 2147483647 0.001 0 % DRGS ArGraSwl ASG 2.5.3 Gradient for Swells. Percentage of the current rated current (DRAT.ARtg) to apply per inductively per percentage of the percent positive deviation from the moving voltage average voltage (RDGS.Av). It is a deviatio ratio of percent and is therefore n unitless. AI96 Dynamic Reactive Current Support 2 0 2147483647 1 0 sec DRGS FilTms ING 2.5.3 Filter Time for Moving Average Voltage (RDGS.VAv). Used to determine amount of dynamic reactive current support. AI97 Dynamic Reactive Current Support 2 0 1000 0.1 0 % DRGS BlkZnV ASG 2.5.3 Block Zone Voltage. Percentage of the nominal voltage (DRCT.VRef) below which no reactive current support shall be applied. AI98 Dynamic Reactive Current Support 2 0 1000 0.1 0 % DRGS HysBlkZnV ASG 2.5.3 Hysteresis Block Zone Voltage. Percentage of the nominal voltage (DRCT.VRef). After being blocked, reactive current support shall not resume until the voltage has been above BlkZnV + HysBlkZnV. AI99 Dynamic Reactive Current Support 2 0 2147483647 1 0 ms DRGS BlkZnTmms ING 2.5.3 Block Zone Time. Time in milliseconds from the beginning of any "sag" event, before which dynamic reactive current support will always continue, regardless of how low voltage may sag. AI100 Dynamic Reactive Current Support 2 0 2147483647 1 0 ms DRGS HoldTmms ING 2.5.3 Hold Time. When the voltage returns to within the deadband limits (RDGS.dbVMin annd RDGS.dbVMax)

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class for this length of time (measured in milliseconds), the "sag" or "swell" event is considered to be over. Reactive current support ends, frozen values are unfrozen, and a new event can begin. AI101 Dynamic Reactive Current Attempted 2 0 2147483647 0.1 0 Amps DRGS ReqA MV 2.5.3 Output. Current output that the mode is attempting to achieve based on the Voltage input and other parameters. AI102 Dynamic Volt-Watt Mode Priority 2 0 number of 1 0 n/a DVWD ModPrio ING 2.10.4 modes AI103 Dynamic Volt-Watt Enabling Time 2 0 2147483647 1 0 sec DVWD WinTms ING 2.3.2 Window AI104 Dynamic Volt-Watt Enabling Ramp 2 0 2147483647 1 0 sec DVWD RmpTms ING 2.3.2 Time AI105 Dynamic Volt-Watt Reversion Timeout 2 0 2147483647 1 0 sec DVWD RvrtTms ING 2.3.2 Period AI106 Dynamic Volt-Watt Signal Meter ID 2 0 2147483647 1 0 n/a DVWD EcpRef4 ORG 2.5.5 AI107 Dynamic Volt-Watt Voltage Reference 2 0 2147483647 0.1 0 Volts MMXN Vol MV 2.5.5 Input. Votltage measurement read from the meter and used as an input to the mode. AI108 Dynamic Volt-Watt Moving Average 2 0 2147483647 0.1 0 Volts DVWD VAv MV 2.5.5 Voltage AI109 Dynamic Volt-Watt Present Delta 2 0 2147483647 0.1 0 Volts DVWD DelV MV 2.5.5 Voltage AI110 Dynamic Volt-Watt Gradient. Signed 2 -2147483648 2147483647 0.001 0 % watts DVWD DynVWGra ASG 2.5.5 quantity that establishes the ratio of per additional Watts supplied (expressed percent in terms of % DRCT.WMax) to the voltage present difference from the moving differen average voltage (expressed as % ce DRCT.VRef). AI111 Dynamic Volt-Watt Filter Time. The 2 0 2147483647 1 0 sec DVWD VWFilTms ASG 2.5.5 time in seconds used to calculate the

4 DVWD.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXN.Vol

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class moving average voltage for dynamic Volt-Watt support. AI112 Dynamic Volt-Watt Lower Deadband. 2 -1000 0 0.1 0 % DVWD DbVWLo ASG 2.5.5 Percentage of the nominal voltage (DRCT.Vref) measured below the moving average voltage. If the present voltage is above this value, no additional Watts shall be supplied. AI113 Dynamic Volt-Watt Upper Deadband. 2 0 1000 0.1 0 % DVWD DbVWHi ASG 2.5.5 Percentage of the nominal voltage (DRCT.Vref) measured above the moving average voltage. If the present voltage is below this value, no additional Watts shall be supplied. AI114 Dynamic Volt-Watt Attempted Output. 2 -2147483648 2147483647 1 0 Watts DVWD ReqWSet MV 2.5.5 Watt output that the mode is attempting to achieve based on the Voltage input and other parameters. AI115 Frequency-Watt Mode Priority 0 number of 1 0 n/a DHFW ModPrty ING 2.10.4 modes AI116 Frequency-Watt Enabling Time 2 0 2147483647 1 0 sec DHFW WinTms ING 2.3.2 Window AI117 Frequency-Watt Enabling Ramp Time 2 0 2147483647 1 0 sec DHFW RmpTms ING 2.3.2 AI118 Frequency-Watt Reversion Timeout 2 0 2147483647 1 0 sec DHFW RvrtTms ING 2.3.2 Period AI119 Frequency-Watt Signal Meter ID 2 0 2147483647 1 0 n/a DHFW EcpRef5 ORG 2.5.3 AI120 Frequency-Watt Frequency Reference 2 0 70000 0.001 0 Hz MMXU Hz MV 2.5.3 Input. Frequency measurement read from the meter and used as an input to the mode. AI121 Frequency-Watt High Starting 2 0 70000 0.001 0 Hz DHFW HzStr ASG 2.5.3 Frequency. Delta frequency between start frequency and nominal grid frequency for high frequency events. AI122 Frequency-Watt High Stopping 2 0 70000 0.001 0 Hz DHFW HzStop ASG 2.5.3 Frequency. Delta frequency between

5 DHFW.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.Hz

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class stop frequency and nominal grid frequency for high frequency events. AI123 Frequency-Watt High Discharging / 2 -2147483648 2147483647 0.001 0 % watts DHFW WGra ASG 2.5.3 Generating Gradient. Signed quantity per % that establishes the ratio of additional Hz diff Watts supplied (expressed in terms of % DRCT.WMax) to the present difference from the moving average frequency (expressed as % of nominal grid frequency). AI124 Frequency-Watt High Charging 2 -2147483648 2147483647 0.001 0 % watts DHFW WChaGra ASG 2.5.3 Gradient. Ratio of additional Watts per % charged to the present difference from Hz diff the moving average frequency AI125 Frequency-Watt Low Starting 2 -70000 0 0.001 0 Hz DLFW HzStr ASG 2.5.3 Frequency. Delta frequency between start frequency and nominal grid frequency for low frequency events. AI126 Frequency-Watt Low Stopping 2 -70000 0 0.001 0 Hz DLFW HzStop ASG 2.5.3 Frequency. Delta frequency between stop frequency and nominal grid frequency for low frequency events. AI127 Frequency-Watt Low Discharging / 2 -2147483648 2147483647 0.001 0 % watts DLFW WGra ASG 2.5.3 Generating Gradient. Signed unit-less per % quantity that establishes the ratio of Hz diff additional Watts supplied (expressed in terms of % DRCT.WMax) to the present difference from the moving average frequency (expressed as % of nominal grid frequency). AI128 Frequency-Watt Low Charging 2 -2147483648 2147483647 0.001 0 % watts DLFW WChaGra ASG 2.5.3 Gradient. Ratio of additional Watts per % charged to the present difference from Hz diff the moving average frequency AI129 Frequency-Watt Start Delay. 2 0 2147483647 1 0 Milli-sec DHFW ActStrDlTmms ING 2.5.3 Intentional delay before function activation for a frequency event AI130 Frequency-Watt Stop Delay. 2 0 2147483647 1 0 Milli-sec DHFW ActStopDlTmm ING 2.5.3 Intentional delay before stoping the s

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class function after a fequency event AI131 Frequency-Watt Ramp Up Time 2 0 2147483647 1 0 sec DLFW OpnLoopMax ING 2.6.2 Constant. Time constant or open loop response time for moving from the current active power target to a higher active power target. AI132 Frequency-Watt Ramp Down Time 2 0 2147483647 1 0 sec DHFW OpnLoopMax ING 2.6.2 Constant. Time constant or open loop response time for moving from the current active power target to a higher active power target. AI133 Frequency-Watt Discharge Ramp Up 2 0 500000 0.1 0 % per DHFW RpuRte ING 2.6.2 Rate sec AI134 Frequency-Watt Discharge Ramp 2 0 500000 0.1 0 % per DHFW RpdRteMax ING 2.6.2 Down Rate sec AI135 Frequency-Watt Charge Ramp Up 2 0 500000 0.1 0 % per DHFW RpuChaRte ING 2.6.2 Rate sec AI136 Frequency-Watt Charge Ramp Down 2 0 500000 0.1 0 % per DHFW RpdChaRteMa ING 2.6.2 Rate sec x AI137 Frequency-Watt High Return Gradient 2 -2147483648 2147483647 0.001 0 % watts DHFW RtnRmpRte ASG 2.5.3 per % Hz diff AI138 Frequency-Watt Low Return Gradient 2 -2147483648 2147483647 0.001 0 % watts DLFW RtnRmpRte ASG 2.5.3 per % Hz diff AI139 Frequency-Watt Attempted Output. 2 -2147483648 2147483647 1 0 Watts DHFW ReqWLim MV 2.5.3 Watt output that the mode is attempting to achieve based on the Frequency input and other parameters. If “Snapshot of Power” is not enabled, this is the maximum active power the outstation will attempt to generate or absorb. AI140 Frequency-Watt Minimum Usable SOC 2 0 1000 0.1 0 % DFWP SocUseMinPct ASG 2.5.3

AI141 Frequency-Watt Maximum Usable 2 0 1000 0.1 0 % DFWP SocUseMaxPc ASG 2.5.3 SOC t

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI142 Active Power Limit Mode Priority 2 0 number of 1 0 n/a DWMX ModPrio ING 2.10.4 modes AI143 Active Power Limit Enabling Time 2 0 2147483647 1 0 sec DWMX WinTms ING 2.3.2 Window. Time window (in seconds) within which to randomly execute a command. If the time window is zero, the command will be executed immediately AI144 Active Power Limit Enabling Ramp 2 0 2147483647 1 0 sec DWMX RmpTms ING 2.3.2 Time. Ramp time, in seconds, for moving from current operational mode settings to new operational mode settings AI145 Active Power Limit Reversion Timeout 2 0 2147483647 1 0 sec DWMX RvrtTms ING 2.3.2 Period. Reversion Timeout Period (in seconds), after which the device will revert to its default status, such as closing the switch to reconnect to the grid or allowing maximum watts output, in case communications are lost or mitigating messages are not received AI146 Active Power Limit Signal Meter ID 2 0 2147483647 1 0 n/a DWMX EcpRef6 ORG 2.6.1 AI147 Active Power Limit Reference Input. 2 -2147483648 2147483647 1 0 Watts MMXU TotW MV 2.6.1 Active Power measurement read from the meter and used as an input to the mode. AI148 Active Power Limit Charge Setpoint. 2 0 1000 0.1 0 % DWMX WLimPct ASG 2.6.1 Limit of imported Watts as a percentage of Maximum Active Power capability, AI149 Active Power Limit Generation 2 0 1000 0.1 0 % DWMN WLimPct ASG 2.6.1 Setpoint. Limit of exported Watts as a percentage of Maximum Active Power capability, AI150 Charge/Discharge Mode Priority 2 0 number of 1 0 n/a DWGC ModPrio ING 2.10.4 modes

6 DWMX.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI151 Charge/Discharge Enabling Time 2 0 2147483647 1 0 sec DWGC WinTms ING 2.3.2 Window AI152 Charge/Discharge Enabling Ramp 2 0 2147483647 1 0 sec DWGC RmpTms ING 2.3.2 Time. Ramp time, in seconds, for moving from current operational mode settings to new operational mode settings AI153 Charge/Discharge Reversion Timeout 2 0 2147483647 1 0 sec DWGC RvrtTms ING 2.3.2 Period AI154 Charge/Discharge Active Power 2 -1000 1000 0.1 0 % DWGC GnWPctSpt ASG 2.6.2 Target. Percentage of maximum active power. AI155 Charge/Discharge Ramp Up Time 2 0 2147483647 1 0 sec DWGC OpnLoopMax ING 2.6.2 Constant. Time constant or open loop response time for moving from the current active power target to a higher active power target. AI156 Charge/Discharge Ramp Down Time 2 0 2147483647 1 0 sec DWGC OpnLoopMax ING 2.6.2 Constant. Time constant or open loop response time for moving from the current active power target to a higher active power target. AI157 Charge/Discharge Discharge Ramp 2 0 500000 0.1 0 % per DWGC RpuRte ASG 2.6.2 Up Rate sec AI158 Charge/Discharge Discharge Ramp 2 0 500000 0.1 0 % per DWGC RpdRteMax ASG 2.6.2 Down Rate sec AI159 Charge/Discharge Charge Ramp Up 2 0 500000 0.1 0 % per DWGC RpuChaRte ASG 2.6.2 Rate sec AI160 Charge/Discharge Charge Ramp 2 0 500000 0.1 0 % per DWGC RpdChaRteMa ASG 2.6.2 Down Rate sec x AI161 Charge/Discharge Minimum Reserve 2 -1000 1000 0.1 0 % DWGC SocUseMinPct ASG 2.6.2 for Storage. The reserve level below which the storage system may be only be discharged in emergency situations, expressed as a percentage of the usable capacity. AI162 Charge/Discharge Maximum Reserve 2 -1000 1000 0.1 0 % DWGC SocUseMaxPc ASG 2.6.2 for Storage. The reserve level above t

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class which the storage system may be only be charged in emergency situations, expressed as a percentage of the usable capacity. AI163 Coordinated Charge/Discharge Mode 2 0 number of 1 0 n/a DTCD ModPrio ING 2.10.4 Priority modes AI164 Coordinated Charge/Discharge 2 0 2147483647 1 0 sec DTCD WinTms ING 2.3.2 Enabling Time Window AI165 Coordinated Charge/Discharge 2 0 2147483647 1 0 sec DTCD RmpTms ING 2.3.2 Enabling Ramp Time. Ramp time, in seconds, for moving from current operational mode settings to new operational mode settings AI166 Coordinated Charge/Discharge 2 0 2147483647 1 0 sec DTCD RvrtTms ING 2.3.2 Reversion Timeout Period AI167 Coordinated Charge/Discharge Target 2 0 1000 0.1 0 % DTCD SocUseTgt ASG 2.6.3 State of Charge. Charge that the Pct system is expected to achieve, as a percentage of the usable capacity. AI168 Coordinated Charge/Discharge Target 2 0 2147483647 1 0 Days DTCD DateTgt ING 2.6.3 Date. Date by which the storage system must reach the target SOC. Days since January 1, 1970, UTC. AI169 Coordinated Charge/Discharge Target 2 0 2147483647 1 0 Millisec DTCD DateTgtTms ING 2.6.3 Time. Time by when the storage onds system must reach the target SOC. Expressed as the number of seconds since the start of Target Date. AI170 Coordinated Charge/Discharge Energy 2 0 2147483647 1 0 Watt- DTCD SocWReq ING 2.6.3 Request. Amount of energy that must hours be transferred from the grid to the charger to move the SOC from the value at the specific time of reference to the target SOC. AI171 Coordinated Charge/Discharge 2 0 2147483647 1 0 sec DTCD ChaDurTms ING 2.6.3 Minimum Charging Duration. Minimum duration to move from the SOC at the time of reference to the target SOC.

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI172 Coordinated Charge/Discharge Date of 2 0 2147483647 1 0 Days DTCD DateTgt ING 2.6.3 Reference. Date that the SOC is measured or computed by the storage system and is the basis for the Energy Request, Minimum Charging Duration, and other parameters AI173 Coordinated Charge/Discharge Time 2 0 2147483647 1 0 Millisec DTCD SocDateTms ING 2.6.3 of Reference. Time that the SOC is onds measured or computed by the storage system and is the basis for the Energy Request, Minimum Charging Duration, and other parameters AI174 Coordinated Charge/Discharge 2 0 2147483647 1 0 sec DTCD ChaDurMax ING 2.6.3 Duration at Maximum Charge Rate. Duration that energy can be stored at the Maximum Charge Rate. AI175 Coordinated Charge/Discharge 2 0 2147483647 1 0 sec DTCD DschDurMax ING 2.6.3 Duration Maximum Discharge Rate. Duration that energy can be delivered at the Maximum Discharge Rate. AI176 Active Power Response Mode #1 2 0 number of 1 0 n/a DPKP ModPrio ING 2.10.4 Priority modes AI177 Active Power Response Mode #1 2 0 2147483647 1 0 sec DPKP WinTms ING 2.3.2 Enabling Time Window AI178 Active Power Response Mode #1 2 0 2147483647 1 0 sec DPKP RmpTms ING 2.3.2 Enabling Ramp Time AI179 Active Power Response Mode #1 2 0 2147483647 1 0 sec DPKP RvrtTms ING 2.3.2 Reversion Timeout Period AI180 Active Power Response Mode #1 2 0 2147483647 1 0 n/a DPKP EcpRef7 ORG 2.6.4.1 Signal Meter ID 2.6.4.2 AI181 Active Power Response Mode #1 2 -2147483648 2147483647 1 0 Watts MMXU TotW MV 2.6.4.1 Reference Power Measured 2.6.4.2 AI182 Active Power Response Mode #1 2 -2147483648 2147483647 1 0 Watts DPKP PkPwrWLim ASG 2.6.4.1 Power Threshold 2.6.4.2 AI183 Active Power Response Mode #1 2 0 1000 0.1 0 % DPKP PkPwrFolPct ING 2.6.4.1

7 DPKPEcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class Ratio 2.6.4.2 AI184 Active Power Response Mode #1 2 0 500000 0.1 0 % per DPKP RpuRte ASG 2.3.4 Ramp Up Rate. Maximum ramp up sec rate. AI185 Active Power Response Mode #1 2 0 500000 0.1 0 % per DPKP RpdRte ASG 2.3.4 Ramp Down Rate. Maximum ramp sec down rate. AI186 Active Power Response Mode #1 2 -2147483648 2147483647 1 0 Watts DPKP ReqWSet MV 2.3.4 Attempted Output. Watt output that the mode is attempting to achieve based on the Watts input and other parameters. AI187 Active Power Response Mode #2 2 0 number of 1 0 n/a DGFL ModPrio ING 2.10.4 Priority modes AI188 Active Power Response Mode #2 2 0 2147483647 1 0 Sec DGFL WinTms ING 2.3.2 Enabling Time Window AI189 Active Power Response Mode #2 2 0 2147483647 1 0 Sec DGFL RmpTms ING 2.3.2 Enabling Ramp Time AI190 Active Power Response Mode #2 2 0 2147483647 1 0 Sec DGFL RvrtTms ING 2.3.2 Reversion Timeout Period AI191 Active Power Response Mode #2 2 0 2147483647 1 0 n/a DGFL EcpRef8 ORG 2.6.4.1 Signal Meter ID 2.6.4.2 AI192 Active Power Response Mode #2 2 -2147483648 2147483647 1 0 Watts MMXU TotW MV 2.6.4.1 Reference Power Measured 2.6.4.2 AI193 Active Power Response Mode #2 2 -2147483648 2147483647 1 0 Watts DGFL PkPwrWLim ASG 2.6.4.1 Power Threshold 2.6.4.2 AI194 Active Power Response Mode #2 2 0 1000 0.1 0 % DGFL PkPwrFolPct ING 2.6.4.1 Ratio 2.6.4.2 AI195 Active Power Response Mode #2 2 0 500000 0.1 0 % per DGFL RpuRte ASG 2.3.4 Ramp Up Rate. Maximum ramp up sec rate. AI196 Active Power Response Mode #2 2 0 500000 0.1 0 % per DGFL RpdRte ASG 2.3.4 Ramp Down Rate. Maximum ramp sec down rate. AI197 Active Power Response Mode #2 2 -2147483648 2147483647 1 0 Watts DGFL ReqWSet MV 2.3.4

8 DGFL.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class Attempted Output. Watt output that the mode is attempting to achieve based on the Watts input and other parameters. AI198 Active Power Response Mode #3 2 0 number of 1 0 n/a DLFL ModPrio ING 2.10.4 Priority modes AI199 Active Power Response Mode #3 2 0 2147483647 1 0 Sec DLFL WinTms ING 2.3.2 Enabling Time Window AI200 Active Power Response Mode #3 2 0 2147483647 1 0 sec DLFL RmpTms ING 2.3.2 Enabling Ramp Time AI201 Active Power Response Mode #3 2 0 2147483647 1 0 sec DLFL RvrtTms ING 2.3.2 Reversion Timeout Period AI202 Active Power Response Mode #3 2 0 2147483647 1 0 n/a DLFL EcpRef9 ORG 2.6.4.1 Signal Meter ID 2.6.4.2 AI203 Active Power Response Mode #3 2 -2147483648 2147483647 1 0 Watts MMXU TotW MV 2.6.4.1 Reference Power Measured 2.6.4.2 AI204 Active Power Response Mode #3 2 -2147483648 2147483647 1 0 Watts DLFL PkPwrWLim ASG 2.6.4.1 Power Threshold 2.6.4.2 AI205 Active Power Response Mode #3 2 0 1000 0.1 0 % DLFL PkPwrFolPct ING 2.6.4.1 Ratio 2.6.4.2 AI206 Active Power Response Mode #3 2 0 500000 0.1 0 % per DLFL RpuRte ASG 2.3.4 Ramp Up Rate. Maximum ramp up sec rate. AI207 Active Power Response Mode #3 2 0 500000 0.1 0 % per DLFL RpdRte ASG 2.3.4 Ramp Down Rate. Maximum ramp sec down rate. AI208 Active Power Response Mode #3 2 -2147483648 2147483647 1 0 Watts DLFL ReqWSet ORG 2.3.4 Attempted Output. Watt output that the mode is attempting to achieve based on the Watts input and other parameters. AI209 AGC Mode Priority 2 0 number of 1 0 n/a DAGC ModPrio ING 2.10.4 modes AI210 AGC Enabling Time Window 2 0 2147483647 1 0 sec DAGC WinTms ING 2.3.2 AI211 AGC Enabling Ramp Time 2 0 2147483647 1 0 sec DAGC RmpTms ING 2.3.2

9 DLFL.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI212 AGC Reversion Timeout Period 2 0 2147483647 1 0 sec DAGC RvrtTms ING 2.3.2 AI213 AGC Active Power Target 2 -2147483648 2147483647 1 0 Watts DAGC GnWSpt APC 2.6.5 AI214 AGC Time Constant Ramp Up Time. 2 0 2147483647 1 0 sec DAGC RmpTms ING 2.3.4 Ramp time, in seconds, for moving from the current active power target to a higher active power target. AI215 AGC Time Constant Ramp Down 2 0 2147483647 1 0 sec DAGC RmpDnTms ING 2.3.4 Time. Ramp time, in seconds, for moving from the current active power target to a lower active power target. AI216 AGC Discharge Ramp Up Rate 2 0 500000 0.1 0 % per DAGC RpuRte ASG 2.3.4 sec AI217 AGC Discharge Ramp Down Rate 2 0 500000 0.1 0 % per DAGC RpdRte ASG 2.3.4 sec AI218 AGC Charge Ramp Up Rate 2 0 500000 0.1 0 % per DAGC RpuChaRte ASG 2.3.4 sec AI219 AGC Charge Ramp Down Rate 2 0 500000 0.1 0 % per DAGC RpdChaRte ASG 2.3.4 sec AI220 AGC Minimum Usable SOC. This is a 2 0 1000 0.1 0 % DAGC SocUseMinPct ASG 2.6.5 range specific to AGC because the DER may be using the rest of the usable capacity for something else. Read-only. AI221 AGC Maximum Usable SOC. This is a 2 0 1000 0.1 0 % DAGC SocUseMaxPc ASG 2.6.5 range specific to AGC because the t DER may be using the rest of the usable capacity for something else. Read-only. AI222 AGC Maximum Watts Available 2 -2147483648 2147483647 1 0 Watts DAGC WMaxAvl MV 2.6.5 AI223 AGC Minimum Watts Available 2 -2147483648 2147483647 1 0 Watts DAGC WMinAvl MV 2.6.5 AI224 AGC Expected State of Charge 2 0 1000 0.1 0 Percent DAGC SocExpc MV 2.6.5 AI225 AGC Expected State of Energy 2 0 2147483647 1 0 Watt- DAGC SoeExpc MV 2.6.5 Hrs AI226 AGC Expected State of Charge Time 2 0 2147483647 1 0 sec DAGC SocExpcTms ING 2.6.5 Interval AI227 Active Power Smoothing Mode Priority 2 0 number of 1 0 n/a DWSM ModPrio ING 2.10.4 modes

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI228 Active Power Smoothing Enabling 2 0 2147483647 1 0 sec DWSM WinTms ING 2.3.2 Time Window AI229 Active Power Smoothing Enabling 2 0 2147483647 1 0 sec DWSM RmpTms ING 2.3.2 Ramp Time AI230 Active Power Smoothing Reversion 2 0 2147483647 1 0 sec DWSM RvrtTms ING 2.3.2 Timeout Period AI231 Active Power Smoothing Signal Meter 2 0 2147483647 1 0 n/a DWSM EcpRef10 ORG 2.6.6 ID AI232 Active Power Smoothing Reference 2 0 2147483647 1 0 n/a MMXU TotW MV 2.6.6 Power Input. Active Power measurement read from the meter and used as an input to the mode. AI233 Active Power Smoothing Gradient. 2 -2147483648 2147483647 0.001 0 Watts DWSM WSmthGra ASG 2.6.6 Signed quantity that establishes the per ratio of additional smoothing Watts Delta- provided to the present delta-watts of watt the reference load or generation. Delta Watts is the difference between the moving average and the present value of the reference power. Positive values of this gradient are for following load (increased reference load results in a dynamic increase in DER output), and negative values are for following generation (increased reference generation results in a dynamic decrease in DER output). AI234 Active Power Smoothing Lower Limit. 2 -2147483648 0 1 0 Watts DWSM WSmthLoLim ASG 2.6.6 Difference in Watts from the moving average of the reference power above which no smoothing shall be applied. AI235 Active Power Smoothing Upper Limit. 2 0 2147483647 1 0 Watts DWSM WSmthHiLim ASG 2.6.6 Difference in Watts from the moving average of the reference power below which no smoothing shall be applied. AI236 Active Power Smoothing Filter Time 2 0 2147483647 1 0 sec DWSM FilTms ING 2.6.6

10 DWSM.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class (sec). Time in seconds used to calculate the moving average of the reference load or generation being smoothed. AI237 Active Power Smoothing Discharge 2 0 500000 0.1 0 Percent DWSM RpuRte ASG 2.3.4 Ramp Up Rate. The maximum per sec generation ramp up rate expressed as a percentage of the Maximum Generation Rate (WMax) per second. AI238 Active Power Smoothing Discharge 2 0 500000 0.1 0 % per DWSM RpdRte ASG 2.3.4 Ramp Down Rate. The maximum sec generation ramp down rate expressed as a percentage of the Maximum Generation Rate (WMax) per second. AI239 Active Power Smoothing Charge 2 0 500000 0.1 0 % per DWSM RpuChaRte ASG 2.3.4 Ramp Up Rate. The maximum sec charging ramp up rate expressed as a percentage of the Maximum Charging Rate (WChaMax) per second. AI240 Active Power Smoothing Charge 2 0 500000 0.1 0 % per DWSM RpdChaRte ASG 2.3.4 Ramp Down Rate. The maximum sec charging ramp down rate expressed as a percentage of the Maximum Charnging Rate (WChaMax) per second. AI241 Active Power Smoothing Attempted 2 -2147483648 2147483647 1 0 Watts DWSM ReqWSet MV 2.3.4 Output. Watt output that the mode is attempting to achieve based on the Watt input and other parameters. AI242 Volt-Watt Mode Priority 2 0 number of 1 0 n/a DVWC ModPrio ING 2.10.4 modes AI243 Volt-Watt Enabling Time Window 2 0 2147483647 1 0 Sec DVWC WinTms ING 2.3.2 AI244 Volt-Watt Enabling Ramp Time 2 0 2147483647 1 0 sec DVWC RmpTms ING 2.3.2 AI245 Volt-Watt Reversion Timeout Period 2 0 2147483647 1 0 sec DVWC RvrtTms ING 2.3.2 AI246 Volt-Watt Signal Meter ID 2 0 2147483647 1 0 n/a DVWC EcpRef11 ORG 2.6.7 AI247 Volt-Watt Reference Voltage Input. 2 0 2147483647 0.1 0 Volts MMXN Vol MV 2.6.7

11 DVWC.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXN.Vol

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class Voltage measurement read from the meter and used as an input to the mode. AI248 Volt-Watt Curve Index. Index of the 2 0 2147483647 1 0 n/a DVWC VWCrv CSG 2.6.7 Volt-Watt curve that should be used by the mode. AI249 Volt-Watt Attempted Output. 2 -2147483648 2147483647 1 0 Watts DVWC ReqWLim MV 2.3.4 Maximum active power the outstation will attempt to generate or absorb based on the Voltage input and selected curve. AI250 Volt-Watt Filter Time (sec) 2 0 2147483647 1 0 sec DVWC FilTms ING 2.6.7 AI251 Volt-Watt Ramp Up Time Constant 2 0 2147483647 1 0 sec DVWC OpnLoopMax ING 2.3.4 AI252 Volt-Watt Ramp Down Time Constant 2 0 2147483647 1 0 sec DVWC OpnLoopMax ING 2.3.4 AI253 Volt-Watt Discharging Ramp Up Rate. 2 0 500000 0.1 0 % per DVWC RpuRte ASG 2.3.4 Maximum ramp up rate. sec AI254 Volt-Watt Discharging Ramp Down 2 0 500000 0.1 0 % per DVWC RpdRte ASG 2.3.4 Rate. Maximum ramp down rate. sec AI255 Volt-Watt Charging Ramp Up Rate. 2 0 500000 0.1 0 % per DVWC RpuChaRte ASG 2.3.4 Maximum charging ramp up rate. sec AI256 Volt-Watt Charging Ramp Down Rate. 2 0 500000 0.1 0 % per DVWC RpdChaRte ASG 2.3.4 Maximum charging ramp down rate. sec AI257 Frequency-Watt Curve Mode Priority 2 0 number of 1 0 n/a DHFW ModPrio ING 2.10.4 modes AI258 Frequency-Watt Curve Enabling Time 2 0 2147483647 1 0 sec DHFW WinTms ING 2.3.2 Window AI259 Frequency-Watt Curve Enabling Ramp 2 0 2147483647 1 0 sec DHFW RmpTms ING 2.3.2 Time AI260 Frequency-Watt Curve Reversion 2 0 2147483647 1 0 sec DHFW RvrtTms ING 2.3.2 Timeout Period AI261 Frequency-Watt Curve Signal Meter ID 2 0 2147483647 1 0 n/a DHFW EcpRef12 ORG 2.6.8 AI262 Frequency-Watt Curve Frequency 2 0 70000 0.001 0 Hz MMXU Hz MV 2.6.8 Reference Input. Frequency measurement read from the meter and used as an input to the mode.

12 DHFW.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.Hz

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI263 Frequency-Watt Curve - Curve Index. 2 0 2147483647 1 0 n/a DHFW HzWCrv CSG 2.6.8 Index of the Frequency-Watt curve that should be used by the mode. AI264 Frequency-Watt Curve – High 2 0 2147483647 1 0 n/a DHFW HysCrv CSG 2.6.8 Frequency Hysteresis Curve Index AI265 Frequency-Watt Curve – Lo Frequency 2 0 2147483647 1 0 n/a DLFW HysCrv CSG 2.6.8 Hysteresis Curve Index AI266 Frequency-Watt Curve Start Delay. 2 0 2147483647 1 0 Milli-sec DHFW ActStrDlTmms ING 2.5.3 Intentional delay before function activation for a frequency event AI267 Frequency-Watt Curve Stop Delay. 2 0 2147483647 1 0 Milli-sec DHFW ActStopDlTmm ING 2.5.3 Intentional delay before stopping the s function after a fequency event AI268 Frequency-Watt Curve Ramp Up Time 2 0 2147483647 1 0 sec DHFW OpnLoopMax ING 2.6.2 Constant. Time constant or open loop response time for moving from the current active power target to a higher active power target. AI269 Frequency-Watt Curve Ramp Down 2 0 2147483647 1 0 sec DHFW OpnLoopMax ING 2.6.2 Time Constant. Time constant or open loop response time for moving from the current active power target to a higher active power target. AI270 Frequency-Watt Curve Discharge 2 0 500000 0.1 0 % per DHFW RpuRte ASG 2.6.2 Ramp Up Rate sec AI271 Frequency-Watt Curve Discharge 2 0 500000 0.1 0 % per DHFW RpdRte ASG 2.6.2 Ramp Down Rate sec AI272 Frequency-Watt Curve Charge Ramp 2 0 500000 0.1 0 % per DHFW RpuChaRte ASG 2.6.2 Up Rate sec AI273 Frequency-Watt Curve Charge Ramp 2 0 500000 0.1 0 % per DHFW RpdChaRte ASG 2.6.2 Down Rate sec AI274 Frequency-Watt Curve Attempted 2 -2147483648 2147483647 1 0 Watts DHFW ReqWLim MV Output. Watt output that the mode is attempting to achieve based on the Frequency input and selected curve. If 2.3.4 “Snapshot of Power” is not enabled, this is the maximum active power the outstation will attempt to generate or

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class absorb. AI275 Frequency-Watt Curve Minimum 2 0 1000 0.1 0 % DHFW SocUseMinPct ASG 2.6.2 Usable SOC

AI276 Frequency-Watt Curve Maximum 2 0 1000 0.1 0 % DHFW SocUseMaxPc ASG 2.6.2 Usable SOC t

AI277 Constant VArs Mode Priority 2 0 number of 1 0 n/a DVAR ModPrio ING 2.10.4 modes AI278 Constant VArs Enabling Time Window 2 0 2147483647 1 0 sec DVAR WinTms ING 2.3.2 AI279 Constant VArs Enabling Ramp Time. 2 0 2147483647 1 0 sec DVAR RmpTms ING 2.3.2 Ramp time, in seconds, for moving from current operational mode settings to new operational mode settings. AI280 Constant VArs Reversion Timeout 2 0 2147483647 1 0 sec DVAR RvrtTms ING 2.3.2 Period AI281 Constant VArs Reactive Power Target. 2 -1000 1000 0.1 0 % DVAR VArTgtPct ASG 2.7.1 Percentage of maximum reactive power. AI282 Constant VArs Ramp Up Time 2 0 2147483647 1 0 sec DVAR OpnLoopMax ING 2.3.4 Constant AI283 Constant VArs Ramp Down Time 2 0 2147483647 1 0 sec DVAR OpnLoopMax ING 2.3.4 Constant AI284 Fixed Power Factor Mode Priority 2 0 number of 1 0 n/a DFPF ModPrio ING 2.10.4 modes AI285 Fixed Power Factor Enabling Time 2 0 2147483647 1 0 sec DFPF WinTms ING 2.3.2 Window AI286 Fixed Power Factor Enabling Ramp 2 0 2147483647 1 0 sec DFPF RmpTms ING 2.3.2 Time AI287 Fixed Power Factor Reversion 2 0 2147483647 1 0 sec DFPF RvrtTms ING 2.3.2 Timeout Period AI288 Fixed Power Factor Setpoint – 2 0 100 0.01 0 None DFPF PFGnTgt ASG 2.7.2 Generation / Discharging AI289 Fixed Power Factor Setpoint - 2 0 100 0.01 0 None DFPF PFLodTgt ASG 2.7.2 Charging AI290 Volt-Var Control Mode Priority 2 0 number of 1 0 n/a DVVR ModPrio ING 2.10.4

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class modes AI291 Volt-VAr Control Enabling Time 2 0 2147483647 1 0 sec DVVR WinTms ING 2.3.2 Window AI292 Volt-VAr Control Enabling Ramp Time 2 0 2147483647 1 0 sec DVVR RmpTms ING 2.3.2 AI293 Volt-VAr Control Reversion Timeout 2 0 2147483647 1 0 sec DVVR RvrtTms ING 2.3.2 Period AI294 Volt-VAr Control Signal Meter ID 2 0 2147483647 1 0 n/a DVVR EcpRef13 ORG 2.7.3 AI295 Volt-VAr Control Voltage Input. 2 0 2147483647 0.1 0 Volts MMXN Vol MV 2.7.3 Voltage measurement read from the meter and used as an input to the mode. AI296 Volt-VAr Control Adjusted Reference 2 0 2147483647 0.1 0 Volts DVVR VRefSet MV 2.7.3 Voltage. The Voltage used as reference for Volt-VAr control. If Autonomous Voltage Reference Adjustment is disabled, this is the same fixed value as the Reference Voltage. AI297 Volt-VAr Curve Index. Index of the 2 0 2147483647 1 0 n/a DVVR VVArCrv CSG 2.7.3 Volt-VAr curve that should be used by the mode. AI298 Volt-VAr Ramp Up Time Constant 2 0 2147483647 1 0 sec DVVR OpnLoopMax ING 2.3.4 AI299 Volt-VAr Ramp Down Time Constant 2 0 2147483647 1 0 sec DVVR OpnLoopMax ING 2.3.4 AI300 Volt-VAr Autonomous Voltage 2 0 2147483647 1 0 sec DVVR VRefTmms ING 2.7.3 Reference Adjustment Time Constant AI301 Volt-VAr Attempted Output. VAr 2 -2147483648 2147483647 1 0 VARs DVVR ReqVAr MV output that the mode is attempting to 2.3.4 achieve based on the Voltage input and selected curve. AI302 Watt-VAr Mode Priority 2 0 number of 1 0 n/a DWVR ModPrio ING 2.10.4 modes AI303 Watt-VAr Enabling Time Window 2 0 2147483647 1 0 sec DWVR WinTms ING 2.3.2 AI304 Watt-VAr Enabling Ramp Time 2 0 2147483647 1 0 sec DWVR RmpTms ING 2.3.2 AI305 Watt-VAr Reversion Timeout Period 2 0 2147483647 1 0 sec DWVR RvrtTms ING 2.3.2

13 DVVR.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXN.Vol

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI306 Watt-VAr Signal Meter ID 2 0 2147483647 1 0 n/a DWVR EcpRef14 ORG 2.7.4 AI307 Watt-VAr Reference Power Input. 2 0 2147483647 1 0 Watts MMXU TotW MV 2.7.4 Power measurement read from the meter and used as an input to the mode. AI308 Watt-VAr Curve Index. Index of the 2 0 2147483647 1 0 n/a DWVR WVArCrv CSG 2.7.4 Watt-VAr curve that should be used by the mode. AI309 Watt-VAr Ramp Up Time Constant 2 0 2147483647 1 0 sec DWVR OpnLoopMax ING 2.3.4 AI310 Watt-VAr Ramp Down Time Constant 2 0 2147483647 1 0 sec DWVR OpnLoopMax ING 2.3.4 AI311 Watt-VAr Attempted Output. VAr 2 -2147483648 2147483647 1 0 VARs DWVR ReqVAr MV output that the mode is attempting to 2.3.4 achieve based on the Watt input and selected curve. AI312 Power Factor Correction Mode Priority 2 0 number of 1 0 n/a DPFC ModPrio ING 2.10.4 modes AI313 Power Factor Correction Enabling 2 0 2147483647 1 0 sec DPFC WinTms ING 2.3.2 Time Window AI314 Power Factor Correction Enabling 2 0 2147483647 1 0 sec DPFC RmpUpRte ASG 2.3.2 Ramp Time AI315 Power Factor Correction Reversion 2 0 2147483647 1 0 sec DPFC RvrtTms ING 2.3.2 Timeout Period AI316 Power Factor Correction Signal Meter 2 0 2147483647 1 0 n/a DPFC EcpRef15 ORG 2.7.5 ID AI317 Power Factor Correction Reference 2 -100 100 0.01 0 None MMXU TotPF MV 2.7.5 Power Factor Input. Power factor measurement read from the meter and used as an input to the mode. AI318 Power Factor Correction Average PF 2 -100 100 0.01 0 None DPFC PFTrg ASG 2.7.5 Target AI319 Power Factor Correction Lower PF 2 -100 100 0.01 0 None DPFC PFCorRef.rang Int 2.7.5 Limit eC AI320 Power Factor Correction Upper PF 2 -100 100 0.01 0 None DPFC PFCorRef.rang Int 2.7.5

14 DWVR.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW 15 DPFC.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotPF

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class Limit eC AI321 Pricing Mode Priority 2 0 number of 1 0 n/a DPRG ModPrio ING 2.10.4 modes AI322 Pricing Mode Enabling Time Window 2 0 2147483647 1 0 sec DPRG WinTms ING 2.3.2 AI323 Pricing Mode Enabling Ramp Time 2 0 2147483647 1 0 sec DPRG RmpTms ASG 2.3.2 AI324 Pricing Mode Reversion Timeout 2 0 2147483647 1 0 sec DPRG RvrtTms ASG 2.3.2 Period AI325 Pricing Mode Setpoint: Hundredths of 2 -2147483648 2147483647 0.01 0 100ths DPRG PrcRef MV 2.8 local currency per Kilowatt-Hr. of local currency AI326 Pricing Mode Time Constant Ramp Up 2 0 2147483647 1 0 sec DPRG OpnLoopMax ING 2.3.4 Time AI327 Pricing Mode Time Constant Ramp 2 0 2147483647 1 0 sec DPRG OpnLoopMax ING 2.3.4 Down Time AI328 Curve Edit Selector 2 1 2147483647 1 0 n/a DGSM InCrv ORG 2.3.3 Index of the curve which is currently being viewed and/or changed. AI329 Curve Mode Type. Enumeration: 2 0 20 1 0 None DGSM ModTyp ENG 2.3.3 (list) <0> Curve is not defined <1> None, dimensionless <2> Volt-Var modes VV11-VV12 <3> Frequency-Watt mode FW22 <4> Watt-VAr mode WP42 <5> Voltage-Watt modes VW51- VW52 <6> Remain Connected <7> Temperature mode <8> Pricing signal mode

High Voltage ride-through curves <9> HVRT Must Trip <10> HVRT Momentary Cessation

Low Voltage ride-through curves <11> LVRT Must Trip <12> LVRT Momentary Cessation

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class

High Frequency ride-through curves <13> HFRT Must Trip <14> HFRT Momentary Cessation

Low Frequency ride-through curves <15> LFRT Must Trip <16> LFRT Momentary Cessation AI330 Curve Number of Points 2 0 100 1 0 n/a FMAR PairArray. CSG 2.3.3 NumPts AI331 Independent (X-Value) Units for Curve 2 0 255 1 0 None FMAR IndpUnits ENG 2.3.3 <0> Curve is not defined (list) <1> Not applicable / Unknown <4> Time <29> Voltage <33> Frequency <38> Watts <23> Celsius Temperature <100> Price in hundredths of local currency <129> Percent Voltage <133> Percent Frequency <138> Percent Watts <233> Frequency Deviation <234+> Other AI332 Dependent (Y-Value) Units for Curve 2 0 255 1 0 None FMAR DepRef ENG 2.3.3 <0> Curve is not defined (list) <1> Not applicable / unknown <2> VArs as percent of max VArs (VARMax) <3> VArs as percent of max available VArs (VArAval) <4> Vars as percent of max Watts (Wmax) - not used <5> Watts as percent of max Watts (Wmax) <6> Watts as percent of frozen active power (DeptSnptRef) <7> Power Factor in EEI notation <8> Volts as a percent of the

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class nominal voltage (VRef) <9> Frequency as a percentage of the Nominal Grid Frequency (ECPNomHz) <99+> Other AI333 Curve Point 1 X-Value 2 see scaling 0 Varies FMAR PairArr.CrvPts[ CSG 2.3.3 table 1].xVal depending on Mode Type AI334 Curve Point 1 Y-Value 2 see scaling 0 Varies FMAR PairArr.CrvPts[ CSG 2.3.3 table 1].yVal depending on Mode Type AI335 Curve Point 2 X-Value 2 see scaling 0 Varies FMAR PairArr.CrvPts[ CSG 2.3.3 table 2].xVal depending on Mode Type AI336 Curve Point 2 Y-Value 2 see scaling 0 Varies FMAR PairArr.CrvPts[ CSG 2.3.3 table 2].yVal depending on Mode Type AI337 – Curve X-Value, Y-Value pairs for curve

AI530 points 3 -99 AI531 Curve Point 100 X-Value 2 see scaling 0 Varies FMAR PairArr.CrvPts[ CSG table 100].xVal 2.3.3 depending on Mode Type AI532 Curve Point 100 Y-Value 2 see scaling 0 Varies FMAR PairArr.CrvPts[ CSG table 100].yVal 2.3.3 depending on Mode Type AI533 System Meter Type of Connection 3 0 99 1 0 None DECP EcpConnType ENS Point. Enumeration: (list) <0> unknown, <1> DER to local EPS 2.1.1 <2> Internal to DER <3> local EPS with load to area EPS (PCC with load) <4> local EPS w/o load to area EPS

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class (PCC without load) <5> Load to local EPS <6> External to DER beyond the PCC <7> External to DER within the local EPS <8> Auxiliary DER Load <9> Group of DERs to the area EPS <99> Other AI534 System Meter Type of Circuit Phases. 3 0 8 1 0 None DECP PhsConnTyp ENS Enumeration: (list) <0> unknown <1> Single phase <2> Split phase <3> 2-phase 2.1.1 <4> 3-phase delta <5> 3-phase wye <6> 3-phase wye grounded <7> 3-phase / 3-wire (inverter type) <8> 3-phase / 4-wire (inverter type) AI535 System Meter Apparent Power 2 0 2 1 0 None DECP ClcTotVA ENG Calculation Method. Calculation (list) method for total apparent power calculation. Enumeration: 2.1.1 <0> unknown <1> vector <2> arithmetic AI536 System Meter Frequency 3 0 70000 0.001 0 Hz MMXU Hz MV 2.4.1 AI537 System Meter Active Power 3 -2147483648 2147483647 1 0 Watts MMXU TotW MV 2.4.1 AI538 System Meter Active Power A 1 -2147483648 2147483647 1 0 Watts MMXU W.phsA.mag WYE 2.4.1 AI539 System Meter Active Power B 1 -2147483648 2147483647 1 0 Watts MMXU W.phsB.mag WYE 2.4.1 AI540 System Meter Active Power C 1 -2147483648 2147483647 1 0 Watts MMXU W.phsC.mag WYE 2.4.1 AI541 System Meter Reactive Power 3 -2147483648 2147483647 1 0 VARs MMXU TotVAr MV 2.4.1 AI542 System Meter Reactive Power A 1 -2147483648 2147483647 1 0 VAr MMXU VAr.phsA.mag WYE 2.4.1 AI543 System Meter Reactive Power B 1 -2147483648 2147483647 1 0 VAr MMXU VAr.phsB.mag WYE 2.4.1 AI544 System Meter Reactive Power C 1 -2147483648 2147483647 1 0 VAr MMXU VAr.phsC.mag WYE 2.4.1 AI545 System Meter Power Factor 3 -100 100 0.01 0 None MMXU TotPF MV 2.4.1 AI546 System Meter Apparent Power 3 -2147483648 2147483647 1 0 VA MMXU TotVA MV 2.4.1

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class AI547 System Meter Phase A Volts 3 0 2147483647 0.1 0 Volts MMXU PhV.phsA.mag WYE 2.4.1 AI548 System Meter Phase A Angle 3 0 3600 0.1 0 Degrees MMXU PhV.phsA.ang WYE 2.4.1 AI549 System Meter Phase B Volts 3 0 2147483647 0.1 0 Volts MMXU PhV.phsB.mag WYE 2.4.1 AI550 System Meter Phase B Angle 3 0 3600 0.1 0 Degrees MMXU PhV.phsB.ang WYE 2.4.1 AI551 System Meter Phase C Volts 3 0 2147483647 0.1 0 Volts MMXU PhV.phsC.mag WYE 2.4.1 AI552 System Meter Phase C Angle 3 0 3600 0.1 0 Degrees MMXU PhV.phsC.ang WYE 2.4.1 AI553 System Meter Average Line to Line 1 0 2147483647 0.1 0 Volts MMXU AvPPVPhs WYE 2.4.1 Voltage AI554 System Meter Current A 1 -2147483648 2147483647 0.1 0 Amps MMXU A.phsA.mag WYE 2.4.1 AI555 System Meter Current B 1 -2147483648 2147483647 0.1 0 Amps MMXU A.phsB.mag WYE 2.4.1 AI556 System Meter Current C 1 -2147483648 2147483647 0.1 0 Amps MMXU A.phsC.mag WYE 2.4.1 AI557 System Meter Active Power – High 3 0 2147483647 1 0 Watts MMXU TotW.rangeC.h MV 2.4.3 Threshold Lim AI558 System Meter Active Power – Low 3 0 2147483647 1 0 Watts MMXU TotW.rangeC.l MV 2.4.3 Threshold Lim AI559 System Meter Reactive Power – High 3 0 2147483647 1 0 VARs MMXU TotVAr.rangeC MV 2.4.3 Threshold .hLim AI560 System Meter Reactive Power – Low 3 0 2147483647 1 0 VARs MMXU TotVAr.rangeC MV 2.4.3 Threshold .lLim AI561 System Meter Power Factor – High 3 -100 100 0.01 0 None MMXU TotPF.rangeC. MV 2.4.3 Threshold hLim AI562 System Meter Power Factor – Low 3 -100 100 0.01 0 None MMXU TotPF.rangeC.l MV 2.4.3 Threshold Lim AI563 System Meter Phase A Volts – High 3 0 2147483647 0.1 0 Volts MMXU PhV.phsA.rang WYE 2.4.3 Threshold eC.hLim AI564 System Meter Phase A Volts – Low 3 0 2147483647 0.1 0 Volts MMXU PhV.phsA.rang WYE 2.4.3 Threshold eC.lLim AI565 System Meter Phase B Volts – High 3 0 2147483647 0.1 0 Volts MMXU PhV.phsB.rang WYE 2.4.3 Threshold eC.hLim AI566 System Meter Phase B Volts – Low 3 0 2147483647 0.1 0 Volts MMXU PhV.phsB.rang WYE 2.4.3 Threshold eC.lLim AI567 System Meter Phase C Volts – High 3 0 2147483647 0.1 0 Volts MMXU PhV.phsC.rang WYE 2.4.3 Threshold eC.hLim AI568 System Meter Phase C Volts – Low 3 0 2147483647 0.1 0 Volts MMXU PhV.phsC.rang WYE 2.4.3 Threshold eC.lLim

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class Schedule Analog Inputs S (S=569 for Running Schedule Index. Index of the 2 0 2147483647 1 0 n/a FSCC ActSchdRef ORG 2.9 this version highest priority schedule that is of the currently running or 0 if no schedule is specifcation) currently running. S+1 Schedule to Edit Selector 3 0 2147483647 1 0 n/a FSCC Schd ORG 2.9 S+2 Selected Schedule Identity 3 0 2147483647 1 0 n/a FSCC Schd ORG 2.9 S+3 Selected Schedule Priority. Priority of 3 1 2147483647 1 0 n/a FSCH SchdPrio ING 2.9 the schedule relative to other running schedules. Lower values have higher priority over higher values. S+4 Selected Schedule Type. 3 0 30 1 0 None ------2.9 Enumeration: (list) <1> Low/High Voltage Ride-Through – Hi Must Trip <2> Low/High Voltage Ride-Through – Low Must Trip <3> Low/High Voltage Ride-Through – Hi Momentary <4> Low/High Voltage Ride-Through – Lo Momentary <5> Low/High Frequency Ride- Through – Hi Must Trip <6> Low/High Frequency Ride- Through – Lo Must Trip <7> Low/High Frequency Ride- Through – Hi Momentary <8> Low/High Frequency Ride- Through – Low Momentary <9> Dynamic Reactive Current Support - On/Off <10> Dynamic Volt-Watt - On/Off <11> Frequency-Watt - On/Off <12> Active Power Limit - Charging <13> Active Power Limit - Generating <14> Charge/Discharge - Percent of Maximum <15> Coordinated Charge/Discharge - SOC Target

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class <16> Active Power Response #1 - On/Off <17> Active Power Response #2 - On/Off <18> Active Power Response #3 - On/Off <19> AGC – Watts <20> Active Power Smoothing - On/Off <21> Volt-Watt – Curve Index <22> Frequency-Watt Curve – Curve Index <23> Frequency-Watt Curve – High Hysteresis <24> Frequency-Watt Curve – Low Hysteresis <25> Constant VArs - Percent of Maximum <26> Fixed Power Factor - Power Factor <27> Volt-VAr – Curve Index <28> Watt-VAr – Curve Index <29> Power Factor Correction - On/Off <30> Reserved - For pricing mode S+5 Selected Schedule Start Date. 3 0 2147483647 1 0 Days ------2.9 Number of days since January 1, 1970, UTC. S+6 Selected Schedule Start Time. 3 0 86400000 1 0 Milli------2.9 Milliseconds since the start of seconds Schedule Start Date. S+7 Selected Schedule Repeat Interval. 3 0 2147483647 1 0 Varies FSCH NxtStrTm TCS 2.9 Interval between actions after the initial occurrence. A zero value means the schedule is not repeated. S+8 Selected Schedule Repeat Interval 3 0 8 1 0 n/a FSCH SchdReuse SPG 2.9 Units. Enumeration: <0> = No Repeat <1> = sec <2> = Minutes

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class <3> = Hours <4> = Days <5> = Weeks <6> = Months <7> = Months on Same Day of Week <8> = Months on Same Day of Week from End S+9 Selected Schedule Validation Status 3 0 4 1 0 n/a FSCH SchdSt ENSS 2.9 chedu leStat e S+10 Selected Schedule Status 2 0 4 1 0 None FSCH SchdSt ENSS 2.9 <0> unknown (list) chedu <1> Not available leStat <2> Inactive e <3> Ready-to-Run <4> Running S+11 Selected Schedule Number of Points 3 0 2147483647 1 0 n/a FSCH NumEntr ING 2.9 S+(2(sp-1) + Selected Schedule Point [1] Time 2 0 2147483647 1 0 sec ------2.9 12) Offset S+(2(sp-1) + Selected Schedule Point[1] Value 2 -2147483648 2147483647 1 0 varies FSCH SchdEntr INS 2.9 13) . ------Selected Schedule Time Offset and 2.9 . Value points 2 - 99. . S+2(sp-1) + Selected Schedule Point[100] Time 2 0 2147483647 1 0 sec ------2.9 12 Offset S+2(sp-1) + Selected Schedule Point [100] Value 2 -2147483648 2147483647 1 0 varies FSCH SchdEntr.val[ INS 2.9 13 100 ] S+212 Schedule 1 Status 2 0 4 1 0 None FSCH SchdSt ENSS 2.9 <0> unknown (list) chedu <1> Not available leStat <2> Inactive e <3> Ready-to-Run <4> Running S+213 Schedule 1 Priority 2 1 Number of 1 0 n/a FSCH SchdPrio ING 2.9 possible schedules

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class S+214 Schedule 1 Active Time Value. This is 2 0 10 1 0 n/a FSCH ActStrTm INS 2.9 the index of the time value entry the schedule is currently running. First entry is 1. Zero if the schedule is not running. . ------2.9 . Schedule #2 . . . Schedule #s-1 points . S+(3(s-1) + Schedule #s Status 2 0 4 1 0 n/a FSCH SchdSt ENSS 2.9 212) chedu leStat e S+(3(s-1) + Schedule #s Priority 2 1 Number of 1 0 n/a FSCH SchdPrio ING 2.9 213) possible schedules S+(3(s-1) + Schedule #s Active Time Value. 2 0 10 1 0 n/a FSCH ActStrTm INS 2.9 214)

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class Meter Historian Analog Inputs HM Meter #1 Type of Connection Point. 3 0 99 1 0 None DECP EcpConnType ENG 2.1.1 Enumeration: (list) ECPC <0> unknown, onnTy <1> DER to local EPS pe <2> Internal to DER <3> local EPS with load to area EPS (PCC with load) <4> local EPS w/o load to area EPS (PCC without load) <5> Load to local EPS <6> External to DER beyond the PCC <7> External to DER within the local EPS <8> Auxiliary DER Load <9> Group of DERs to the area EPS <99> Other HM + 1 Meter #1 DER Input/Output Included. 3 0 3 1 0 None DECP DERMsIncl SPG 2.1.1 Enumeration: (list) <0> unknown <1> metered value does not include the input/output of the DER <2> metered value includes all the input/output of the DER <3> other HM + 2 Meter #1 Type of Circuit Phases. 3 0 8 1 0 None DECP PhsConnTyp ENG 2.4.1 Enumeration: (list) Phas <0> unknown eType <1> Single phase <2> Split phase <3> 2-phase <4> 3-phase delta <5> 3-phase wye <6> 3-phase wye grounded <7> 3-phase / 3-wire (inverter type) <8> 3-phase / 4-wire (inverter type) HM + 3 Meter #1 Apparent Power Calculation 2 0 2 1 0 None MMXU ClcTotVA ENG 2.7 Method. Calculation method for total (list) apparent power calculation. Enumeration:

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class <0> Reserved <1> Vector <2> Arithmetic HM + 4 Meter #1 Frequency 3 0 70000 0.001 0 Hz MMXU Hz MV 2.4.1 HM + 5 Meter #1 Active Power 3 -2147483648 2147483647 1 0 Watts MMXU TotW MV 2.4.1 HM + 6 Meter #1 Active Power A 1 -2147483648 2147483647 1 0 Watts MMXU W.phsA.mag WYE 2.4.1 HM + 7 Meter #1 Active Power B 1 -2147483648 2147483647 1 0 Watts MMXU W.phsB.mag WYE 2.4.1 HM + 8 Meter #1 Active Power C 1 -2147483648 2147483647 1 0 Watts MMXU W.phsC.mag WYE 2.4.1 HM + 9 Meter #1 Reactive Power 3 -2147483648 2147483647 1 0 VARs MMXU TotVAr MV 2.4.1 HM + 10 Met er #1 Reactive Power A 1 -2147483648 2147483647 1 0 VAr MMXU VAr.phsA.mag WYE 2.4.1 HM + 11 Meter #1 Reactive Power B 1 -2147483648 2147483647 1 0 VAr MMXU VAr.phsB.mag WYE 2.4.1 HM + 12 Meter #1 Reactive Power C 1 -2147483648 2147483647 1 0 VAr MMXU VAr.phsC.mag WYE 2.4.1 HM + 13 Meter #1 Power Factor 3 -100 100 0.01 0 None MMXU TotPF MV 2.4.1 HM + 14 Meter #1 Apparent Power 3 -2147483648 2147483647 1 0 VA MMXU TotVA MV 2.4.1 HM + 15 Meter #1 Phase A Volts 3 0 2147483647 0.1 0 Volts MMXU PhV.phsA.mag WYE 2.4.1 HM + 16 Meter #1 Phase A Angle 3 0 3600 0.1 0 Degrees MMXU PhV.phsA.ang WYE 2.4.1 HM + 17 Meter #1 Phase B Volts 3 0 2147483647 0.1 0 Volts MMXU PhV.phsB.mag WYE 2.4.1 HM + 18 Meter #1 Phase B Angle 3 0 3600 0.1 0 Degrees MMXU PhV.phsB.ang WYE 2.4.1 HM + 19 Meter #1 Phase C Volts 3 0 2147483647 0.1 0 Volts MMXU PhV.phsC.mag WYE 2.4.1 HM + 20 Meter #1 Phase C Angle 3 0 3600 0.1 0 Degrees MMXU PhV.phsC.ang WYE 2.4.1 HM + 21 Meter #1 Average Line to Line Voltage 1 0 2147483647 0.1 0 Volts MMXU AvPPVPhs WYE 2.4.1 HM + 22 Meter #1 Current A 1 -2147483648 2147483647 0.1 0 Amps MMXU A.phsA.mag WYE 2.4.1 HM + 23 Meter #1 Current B 1 -2147483648 2147483647 0.1 0 Amps MMXU A.phsB.mag WYE 2.4.1 HM + 24 Meter #1 Current C 1 -2147483648 2147483647 0.1 0 Amps MMXU A.phsC.mag WYE 2.4.1 HM + 25 Meter #1 Active Power – High 3 0 2147483647 1 0 Watts MMXU TotW.rangeC.h MV 2.4.3 Threshold Lim HM + 26 Met er #1 Active Power – Low 3 0 2147483647 1 0 Watts MMXU TotW.rangeC.l MV 2.4.3 Threshold Lim HM + 27 Meter #1 Reactive Power – High 3 0 2147483647 1 0 VARs MMXU TotVAr.rangeC MV 2.4.3 Threshold .hLim HM + 28 Meter #1 Reactive Power – Low 3 0 2147483647 1 0 VARs MMXU TotVAr.rangeC MV 2.4.3 Threshold .lLim

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class HM + 29 Meter #1 Power Factor – High 3 -100 100 0.01 0 None MMXU TotPF.rangeC. MV 2.4.3 Threshold hLim HM + 30 Meter #1 Power Factor – Low 3 -100 100 0.01 0 None MMXU TotPF.rangeC.l MV 2.4.3 Threshold Lim HM + 31 Meter #1 Phase A Volts – High 3 0 2147483647 0.1 0 Volts MMXU PhV.phsA.rang WYE 2.4.3 Threshold eC.hLim HM + 32 Meter #1 Phase A Volts – Low 3 0 2147483647 0.1 0 Volts MMXU PhV.phsA.rang WYE 2.4.3 Threshold eC.lLim HM + 33 Meter #1 Phase B Volts – High 3 0 2147483647 0.1 0 Volts MMXU PhV.phsB.rang WYE 2.4.3 Threshold eC.hLim HM + 34 Meter #1 Phase B Volts – Low 3 0 2147483647 0.1 0 Volts MMXU PhV.phsB.rang WYE 2.4.3 Threshold eC.lLim HM + 35 Meter #1 Phase C Volts – High 3 0 2147483647 0.1 0 Volts MMXU PhV.phsC.rang WYE 2.4.3 Threshold eC.hLim HM + 36 Meter #1 Phase C Volts – Low 3 0 2147483647 0.1 0 Volts MMXU PhV.phsC.rang WYE 2.4.3 Threshold eC.lLim . . Meter #2 . . . #m-1 points . HM + Meter #m Type of Connection Point. 3 0 99 1 0 None DECP EcpConnType ENG 2.1.1 mhai(m) Enumeration: (list) ECPC <0> unknown, onnTy <1> DER to local EPS pe <2> Internal to DER <3> local EPS with load to area EPS (PCC with load) <4> local EPS w/o load to area EPS (PCC without load) <5> Load to local EPS <6> External to DER beyond the PCC <7> External to DER within the local EPS <8> Auxiliary DER Load <9> Group of DERs to the area EPS <99> Other HM + Meter #m DER Input/Output Included. 3 0 3 1 0 None DECP DERMsIncl SPG 2.1.1 mhai(m)+ 1 Enumeration: (list) <0> unknown

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class <1> metered value does not include the input/output of the DER <2> metered value includes all the input/output of the DER <3> other HM + Meter #m Type of Circuit Phases. 3 0 8 1 0 None DECP PhsConnTyp ENG 2.4.1 mhai(m)+ 2 Enumeration: (list) Phas <0> unknown eType <1> Single phase <2> Split phase <3> 2-phase <4> 3-phase delta <5> 3-phase wye <6> 3-phase wye grounded <7> 3-phase / 3-wire (inverter type) <8> 3-phase / 4-wire (inverter type) HM + Meter #m Apparent Power Calculation 2 0 2 1 0 None MMXU ClcTotVA ENG 2.4.1 mhai(m)+ 3 Method. Calculation method for total (list) apparent power calculation. Enumeration: <0> Reserved <1> Vector <2> Arithmetic HM + Meter #m Frequency 3 0 70000 0.001 0 Hz MMXU Hz MV 2.4.1 mhai(m)+ 4 HM + Meter #m Active Power 3 -2147483648 2147483647 1 0 Watts MMXU TotW MV 2.4.1 mhai(m)+ 5 HM + Meter #m Active Power A 1 -2147483648 2147483647 1 0 Watts MMXU W.phsA.mag WYE 2.4.1 mhai(m)+ 6 HM + Meter #m Active Power B 1 -2147483648 2147483647 1 0 Watts MMXU W.phsB.mag WYE 2.4.1 mhai(m)+ 7 HM + Meter #m Active Power C 1 -2147483648 2147483647 1 0 Watts MMXU W.phsC.mag WYE 2.4.1 mhai(m)+ 8

HM + Meter #m Reactive Power 3 -2147483648 2147483647 1 0 VARs MMXU TotVAr MV 2.4.1 mhai(m)+ 9

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class HM + Meter #m Reactive Power A 1 -2147483648 2147483647 1 0 VAr MMXU VAr.phsA.mag WYE 2.4.1 mhai(m)+ 10 HM + Meter #m Reactive Power B 1 -2147483648 2147483647 1 0 VAr MMXU VAr.phsB.mag WYE 2.4.1 mhai(m)+ 11 HM + Meter #m Reactive Power C 1 -2147483648 2147483647 1 0 VAr MMXU VAr.phsC.mag WYE 2.4.1 mhai(m)+ 12 HM + Meter #m Power Factor 3 -100 100 0.01 0 None MMXU TotPF MV 2.4.1 mhai(m)+ 13 HM + Meter #m Apparent Power 3 -2147483648 2147483647 1 0 VA MMXU TotVA MV 2.4.1 mhai(m)+ 14 HM + Meter #m Phase A Volts 3 0 2147483647 0.1 0 Volts MMXU PhV.phsA.mag WYE 2.4.1 mhai(m)+ 15 HM + Meter #m Phase A Angle 3 0 3600 0.1 0 Degrees MMXU PhV.phsA.ang WYE 2.4.1 mhai(m)+ 16 HM + Meter #m Phase B Volts 3 0 2147483647 0.1 0 Volts MMXU PhV.phsB.mag WYE 2.4.1 mhai(m)+ 17 HM + Meter #m Phase B Angle 3 0 3600 0.1 0 Degrees MMXU PhV.phsB.ang WYE 2.4.1 mhai(m)+ 18 HM + Meter #m Phase C Volts 3 0 2147483647 0.1 0 Volts MMXU PhV.phsC.mag WYE 2.4.1 mhai(m)+ 19 HM + Meter #m Phase C Angle 3 0 3600 0.1 0 Degrees MMXU PhV.phsC.ang WYE 2.4.1 mhai(m)+ 20 HM + Meter #m Average Line to Line 1 0 2147483647 0.1 0 Volts MMXU AvPPVPhs WYE 2.4.1 mhai(m)+ 21 Voltage HM + Meter #m Current A 1 -2147483648 2147483647 0.1 0 Amps MMXU A.phsA.mag WYE 2.4.1 mhai(m)+ 22 HM + Meter #m Current B 1 -2147483648 2147483647 0.1 0 Amps MMXU A.phsB.mag WYE 2.4.1 mhai(m)+ 23 HM + Meter #m Current C 1 -2147483648 2147483647 0.1 0 Amps MMXU A.phsC.mag WYE 2.4.1 mhai(m)+ 24

HM + Meter #m Active Power – High 3 0 2147483647 1 0 Watts MMXU TotW.rangeC.h MV 2.4.3 mhai(m)+ 25 Threshold Lim

Page 111 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class HM + Meter #m Active Power – Low 3 0 2147483647 1 0 Watts MMXU TotW.rangeC.l MV 2.4.3 mhai(m)+ 26 Threshold Lim HM + Meter #m Reactive Power – High 3 0 2147483647 1 0 VARs MMXU TotVAr.rangeC MV 2.4.3 mhai(m)+ 27 Threshold .hLim HM + Meter #m Reactive Power – Low 3 0 2147483647 1 0 VARs MMXU TotVAr.rangeC MV 2.4.3 mhai(m)+ 28 Threshold .lLim HM + Meter #m Power Factor – High 3 -100 100 0.01 0 None MMXU TotPF.rangeC. MV 2.4.3 mhai(m)+ 29 Threshold hLim HM + Meter #m Power Factor – Low 3 -100 100 0.01 0 None MMXU TotPF.rangeC.l MV 2.4.3 mhai(m)+ 30 Threshold Lim HM + Meter #m Phase A Volts – High 3 0 2147483647 0.1 0 Volts MMXU PhV.phsA.rang WYE 2.4.3 mhai(m)+ 31 Threshold eC.hLim HM + Meter #m Phase A Volts – Low 3 0 2147483647 0.1 0 Volts MMXU PhV.phsA.rang WYE 2.4.3 mhai(m)+ 32 Thresho ld eC.lLim HM + Meter #m Phase B Volts – High 3 0 2147483647 0.1 0 Volts MMXU PhV.phsB.rang WYE 2.4.3 mhai(m)+ 33 Threshold eC.hLim HM + Meter #m Phase B Volts – Low 3 0 2147483647 0.1 0 Volts MMXU PhV.phsB.rang WYE 2.4.3 mhai(m)+ 34 Threshold eC.lLim HM + Meter #m Phase C Volts – High 3 0 2147483647 0.1 0 Volts MMXU PhV.phsC.rang WYE 2.4.3 mhai(m)+ 35 Threshold eC.hLim HM + Meter #m Phase C Volts – Low 3 0 2147483647 0.1 0 Volts MMXU PhV.phsC.rang WYE 2.4.3 mhai(m)+ 36 Threshold eC.lLim

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class DER Unit Historian Analog Inputs HDU DER Unit #1 Unit Type. Enumeration: 3 0 99 1 0 None DSTO DERTyp ENG <0> unknown (list) <1> Diesel / gas engine <2> Gas Turbine engine <3> PV <4> PV plus Storage <5> Lithium Ion Battery Storage <6> Fuel cell <7> Hydro generator <8> Wind turbine <9> Flow battery storage <10> Air compression storage <11> Flywheel storage <12> Capacitor storage <13> Vehicle-to-Grid (V2G) <98> Not applicable / Unknown <99> Other HDU + 1 DER Unit #1 Nameplate Energy 2 0 2147483647 1 0 Amp-hrs DSTO WhMaxRtg ASG Capacity. Nameplate energy capacity or Watt- for the DER unit expressed in Storage hrs Capacity Units. HDU + 2 IEEE 1547 Normal Operating 3 0 2 1 0 None ------Performance Category. Enumeration: (list) <0> unknown <1> Category A <2> Category B HDU + 3 IEEE 1547 Abnormal Operating 3 0 3 1 0 None ------Performance Category. Enumeration: (list) <0> unknown <1> Category I <2> Category II <3> Category III HDU + 4 DER Unit #1 Maximum Apparent 2 0 2147483647 1 0 VA DGEN VAMax ASG 2.4.1 Generation Power HDU + 5 DER Unit #1 Maximum Apparent 2 -2147483648 0 1 0 VA DSTO ChaVAMax ASG 2.4.1 Charging Power HDU + 6 DER Unit #1 Operational Time. Time 3 0 2147483647 1 0 sec DGEN GnOpTms ING 2.4.1 in seconds since commissioning.

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class HDU + 7 DER Unit #1 Connection Time. 3 0 2147483647 1 0 Hours DGEN OpTmRs ING 2.4.1 Number of hours the DER unit has been connected to the power system. HDU + 8 DER Unit #1 Available Active 1 0 2147483647 1 0 W DSTO WAvlUp MV 2.4.1 Generation Power HDU + 9 DER Unit #1 Available Active Charging 1 -2147483648 0 1 0 W DSTO WAvlDn MV 2.4.1 Power HDU + 10 DER Unit #1 Available Reactive 1 0 2147483647 1 0 VAr DGEN TotIvarAvl MV 2.4.1 Injection Power HDU + 11 DER Unit #1 Available Reactive 1 -2147483648 0 1 0 VAr DGEN TotAvarAvl MV 2.4.1 Absorption Power HDU + 12 DER Unit #1 Non-impacting Injection 2 0 2147483647 1 0 VARs DGEN IvarAvl MV 2.4.1 VArs Available. VArs that can be injected without impacting Active Power Output HDU + 13 DER Unit #1 Non-impacting 2 -2147483648 0 1 0 VARs DGEN AvarAvl MV 2.4.1 Absorption VArs Available. VArs that can be absorbed without impacting Active Power Output . DER Unit #2 . . . . DER Unit #u-1 . points . HDU + DER Unit #u Unit Type. Enumeration: 3 0 99 1 0 None DSTO DERTyp ENG duhai(u) <0> Unknown (list) <1> Diesel / gas engine <2> Gas Turbine engine <3> PV <4> PV plus Storage <5> Lithium Ion Battery Storage <6> Fuel cell <7> Hydro generator <8> Wind turbine <9> Flow battery storage <10> Air compression storage <11> Flywheel storage <12> Capacitor storage <13> Vehicle-to-Grid (V2G) <98> Not applicable / Unknown <99> Other

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class HDU + DER Unit #u Nameplate Energy 2 0 2147483647 1 0 Amp-hrs DSTO WhMaxRtg ASG duhai(u)+1 Capacity. Nameplate energy capacity or Watt- for the DER unit expressed in Storage hrs Capacity Units. HDU + IEEE 1547 Normal Operating 3 0 2 1 0 None ------duhai(u)+2 Performance Category. Enumeration: (list) <0> unknown <1> Category A <2> Category B HDU + IEEE 1547 Abnormal Operating 3 0 3 1 0 None ------duhai(u)+3 Performance Category. Enumeration: (list) <0> unknown <1> Category I <2> Category II <3> Category III HDU + DER Unit #u Maximum Apparent 2 0 2147483647 1 0 VA DGEN VAMax ASG 2.4.1 duhai(u)+4 Power

HDU + DER Unit #u Maximum Apparent 2 -2147483648 0 1 0 VA DSTO ChaVAMax ASG 2.4.1 duhai(u)+5 Charging Power

HDU + DER Unit #u Operational Time. Time 3 0 2147483647 1 0 sec DGEN GnOpTms ING 2.4.1 duhai(u)+6 in seconds since commissioning.

HDU + DER Unit #u Connection Time. 3 0 2147483647 1 0 Hours DGEN OpTmRs ING 2.4.1 duhai(u)+7 Number of hours the DER unit has been connected to the power system. HDU + DER Unit #u Available Active 1 0 2147483647 1 0 W DSTO WAvlUp MV 2.4.1 duhai(u)+8 Generation Power

HDU + DER Unit #u Available Active Charging 1 -2147483648 0 1 0 W DSTO WAvlDn MV 2.4.1 duhai(u)+9 Power

HDU + DER Unit #u Available Reactive 1 0 2147483647 1 0 VAr DGEN TotIvarAvl MV 2.4.1 duhai(u)+10 Injection Power

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class HDU + DER Unit #u Available Reactive 1 -2147483648 0 1 0 VAr DGEN TotAvarAvl MV 2.4.1 duhai(u)+11 Absorption Power

HDU + DER Unit #u Non-impacting Injection 2 -2147483648 2147483647 1 0 VARs DGEN IvarAvl MV 2.4.1 duhai(u)+12 VArs Available. VArs that can be injected without impacting Active Power Output HDU + DER Unit #u Non-impacting 2 -2147483648 0 1 0 VARs DGEN AvarAvl MV 2.4.1 duhai(u)+13 Absorption VArs Available. VArs that can be absorbed without impacting Active Power Output Inverter Historian Analog Input Points HI Inverter #1 Apparent Power 2 0 2 1 0 None MMXU ClcTotVA ENG Calculation Method. Calculation (list) method for total apparent power calculation. Enumeration: <0> Reserved <1> Vector <2> Arithmetic HI + 1 Inverter #1 Active Power Target 1 -2147483648 2147483647 1 0 Watts DINV WTgt ASG HI + 2 Inverter #1 Reactive Power Target 1 -2147483648 2147483647 1 0 VARs DINV VArTgtPct ASG HI + 3 Inverter #1 Active Power. Present 3 -2147483648 2147483647 1 0 Watts MMXU TotW MV 2.4.1 active power measurement. HI + 4 Inverter #1 Reactive Power. Present 3 -2147483648 2147483647 1 0 VARs MMXU TotVAr MV 2.4.1 reactive power measurement. HI + 5 Inverter #1 Power Factor 2 -100 100 0.01 0 None MMXU TotPF MV 2.4.1 HI + 6 Inverter #1 Apparent Power 2 -2147483648 2147483647 1 0 VA MMXU TotVA MV 2.4.1 HI + 7 Inverter #1 DC Input Power 3 0 2147483647 1 0 Watts MMDC Watt MV 2.4.1 HI + 8 Inverter #1 DC Voltage 1 0 2147483647 0.1 0 Volts MMDC Vol MV 2.4.1 HI + 9 Inverter #1 DC Current 1 -2147483648 2147483647 0.1 0 Amps MMDC Amp 2.4.1 HI + 10 Inverter #1 Average Line to Neutral 2 0 2147483647 0.1 0 Volts MMXU PhV Wye 2.4.1 Voltage. AC voltage measurement. HI + 11 Inverter #1 Voltage Phase A to B. AC 2 0 2147483647 0.1 0 Volts MMXU PPV.phsAB DEL 2.4.1 voltage measurement. HI + 12 Inverter #1 Voltage Phase B to C. AC 2 0 2147483647 0.1 0 Volts MMXU PPV.phsBC DEL 2.4.1 voltage measurement.

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class HI + 13 Inverter #1 Voltage Phase C to A. AC 2 0 2147483647 0.1 0 Volts MMXU PPV.phsCA DEL 2.4.1 voltage measurement. HI + 14 Inverter #1 AC Current. AC current 2 -2147483648 2147483647 0.1 0 Amps MMXU A WYE 2.4.1 measurement. HI + 15 Inverter #1 Current Phase A. AC 2 -2147483648 2147483647 0.1 0 Amps MMXU A.phsA WYE 2.4.1 current measurement. HI + 16 Inverter #1 Current Phase B. AC 2 -2147483648 2147483647 0.1 0 Amps MMXU A.phsB WYE 2.4.1 current measurement. HI + 17 Inverter #1 Current Phase C. AC 2 -2147483648 2147483647 0.1 0 Amps MMXU A.phsC WYE 2.4.1 current measurement. HI + 18 Inverter #1 Internal (Cabinet) 2 -200 200 0.1 0 Deg C DINV EnclTmp MV 2.4.1 Temperature HI + 19 Inverter #1 Heat Sink Temperature 2 -200 200 0.1 0 Deg C DINV HeatSinkTmp MV 2.4.1 HI + 20 Inverter #1 Transformer Temperature 2 -200 200 0.1 0 Deg C DINV TrfTmp MV 2.4.1 HI + 21 Inverter #1 Active Power Output - 2 0 2147483647 1 0 Watts MMXU TotW.RangeC. MV 2.4.3 High Threshold hLim HI + 22 Inverter #1 Active Power Output - Low 2 0 2147483647 1 0 Watts MMXU TotW.RangeC. MV 2.4.3 Threshold lLim HI + 23 Inverter #1 Reactive Power Output – 2 0 2147483647 1 0 VARs MMXU TotVAr.rangeC MV 2.4.3 High Threshold .hLim HI + 24 Inverter #1 Reactive Power Output – 2 0 2147483647 1 0 VARs MMXU TotVAr.rangeC MV 2.4.3 Low Threshold .lLim HI + 25 Inverter #1 Current Output Frequency 2 0 70000 1000 0 Hz MMXU Hz.rangeC.hLi MV 2.4.3 – High Threshold m HI + 26 Inverter #1 Current Output Frequency 2 0 70000 1000 0 Hz MMXU Hz.rangeC.lLi MV 2.4.3 – Low Threshold m HI + 27 Inverter #1 DC Inverter Input Power - 2 0 2147483647 1 0 Watts MMDC Watt.RangeC. MV 2.4.3 High Threshold hLim HI + 28 Inverter #1 DC Inverter Input Power - 2 0 2147483647 1 0 Watts MMDC Watt.RangeC.l MV 2.4.3 Low Threshold Lim HI + 29 Inverter #1 DC Current Available – 2 -2147483648 2147483647 0.1 0 Amps MMDC Amp.RangeC. MV 2.4.3 High Threshold hLim HI + 30 Inverter #1 DC Current Available – 2 -2147483648 2147483647 0.1 0 Amps MMDC Amp.RangeC.l MV 2.4.3 Low Threshold Lim HI + 31 Inverter #1 DC Voltage Between DER 2 0 2147483647 0.1 0 Volts MMDC Vol.RangeC.hL MV 2.4.3 System and Inverter – High Threshold im

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class HI + 32 Inverter #1 DC Voltage Between DER 2 0 2147483647 0.1 0 Volts MMDC Vol.RangeC.lLi MV 2.4.3 System and Inverter – Low Threshold m . . Inverter #2 . . . Inverter #i-1 points . HI + ihai(i) Inverter #i Apparent Power Calculation 2 0 2 1 0 None MMXU ClcTotVA ENG Method. Calculation method for total (list) apparent power calculation. Enumeration: <0> Reserved <1> Vector <2> Arithmetic HI + ihai(i) + Inverter #i Active Power Target 2 -2147483648 2147483647 1 0 Watts DINV WTgt ASG 1 HI + ihai(i) + Inverter #i Reactive Power Target 2 -2147483648 2147483647 1 0 VARs DINV VArTgtPct ASG 2 HI + ihai(i) + Inverter #i Active Power 3 -2147483648 2147483647 1 0 Watts MMXU TotW MV 2.4.1 3 HI + ihai(i) + Inverter #i Reactive Power 3 -2147483648 2147483647 1 0 VARs MMXU TotVAr MV 2.4.1 4 HI + ihai(i) + Inverter #i Power Factor 2 -100 100 0.01 0 None MMXU TotPF MV 2.4.1 5 HI + ihai(i) + Inverter #i Apparent Power 2 -2147483648 2147483647 1 0 VA MMXU TotVA MV 2.4.1 6 HI + ihai(i) + Inverer #i DC Input Power 3 0 2147483647 1 0 Watts MMDC Watt MV 2.4.1 7 HI + ihai(i) + Inverter #i DC Voltage 2 0 2147483647 0.1 0 Volts MMDC Vol MV 2.4.1 8 HI + ihai(i) + Inverter #i DC Current 2 -2147483648 2147483647 0.1 0 Amps MMDC Amp 2.4.1 9 HI + ihai(i) + Inverter #i Average Line to Neutral 2 0 2147483647 0.1 0 Volts MMXU PhV Wye 2.4.1 10 Voltage. AC voltage measurement. HI + ihai(i) + Inverter #i Voltage Phase A to B. AC 2 0 2147483647 0.1 0 Volts MMXU PPV.phsAB DEL 2.4.1 11 voltage measurement. HI + ihai(i) + Inverter #i Voltage Phase B to C. AC 2 0 2147483647 0.1 0 Volts MMXU PPV.phsBC DEL 2.4.1 12 voltage measurement. HI + ihai(i) + Inverter #i Voltage Phase C to A. AC 2 0 2147483647 0.1 0 Volts MMXU PPV.phsCA DEL 2.4.1

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class 13 voltage measurement. HI + ihai(i) + Inverter #i Current. AC current 2 -2147483648 2147483647 0.1 0 Amps MMXU A WYE 2.4.1 14 measurement. HI + ihai(i) + Inverter #i Current Phase A. AC 2 -2147483648 2147483647 0.1 0 Amps MMXU A.phsA WYE 2.4.1 15 current measurement. HI + ihai(i) + Inverter #i Current Phase B. AC 2 -2147483648 2147483647 0.1 0 Amps MMXU A.phsB WYE 2.4.1 16 current measurement. HI + ihai(i) + Inverter #i Current Phase C. AC 2 -2147483648 2147483647 0.1 0 Amps MMXU A.phsC WYE 2.4.1 17 current measurement. HI + ihai(i) + Inverter #i Internal (Cabinet) 2 -200 200 0.1 0 Deg C DINV EnclTmp MV 2.6.2 18 Temperature HI + ihai(i) + Inverter #i Heat Sink Temperature 2 -200 200 0.1 0 Deg C DINV HeatSinkTmp MV 2.4.1 19 HI + ihai(i) + Inverter #i Transformer Temperature 2 -200 200 0.1 0 Deg C DINV TrfTmp MV 2.4.1 20 HI + ihai(i) + Inverter #i Active Power Output - High 2 0 2147483647 1 0 Watts MMXU TotW MV 2.4.3 21 Threshold HI + ihai(i) + Inverter #i Active Power Output - Low 2 0 2147483647 1 0 Watts MMXU TotW MV 2.4.3 22 Threshold HI + ihai(i) + Inverter #i Reactive Power Output – 2 0 2147483647 1 0 VARs MMXU TotVAr MV 2.4.3 23 High Threshold HI + ihai(i) + Inverter #i Reactive Power Output – 2 0 2147483647 1 0 VARs MMXU TotVAr MV 2.4.3 24 Low Threshold HI + ihai(i) + Inverter #i Current Output Frequency – 2 0 70000 0.001 0 Hz MMXU Hz MV 2.4.3 25 High Threshold HI + ihai(i) + Inverter #i Current Output Frequency – 2 0 70000 0.001 0 Hz MMXU Hz MV 2.4.3 26 Low Threshold HI + ihai(i) + Inverter #i DC Inverter Input Power - 2 0 2147483647 1 0 Watts MMDC Watt MV 2.4.3 27 High Threshold HI + ihai(i) + Inverter #i DC Inverter Input Power - 2 0 2147483647 1 0 Watts MMDC Watt MV 2.4.3 28 Low Threshold HI + ihai(i) + Inverter #i DC Current Available – High 2 -2147483648 2147483647 0.1 0 Amps MMDC Amp MV 2.4.3 29 Threshold HI + ihai(i) + Inverter #i DC Current Available – Low 2 -2147483648 2147483647 0.1 0 Amps MMDC Amp MV 2.4.3 30 Threshold HI + ihai(i) + Inverter #i DC Voltage Between DER 2 0 2147483647 0.1 0 Volts MMDC Vol MV 2.4.3

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class 31 System and Inverter – High Threshold HI + ihai(i) + Inverter #i DC Voltage Between DER 2 0 2147483647 0.1 0 Volts MMDC Vol MV 2.4.3 32 System and Inverter – Low Threshold Battery Historian Analog Inputs HB Battery Bank #1 Type of Storage. 2 0 99 1 0 None DBAT BatTyp ENG Enumeration: (list) <0> n/a, Unknown <1> Lead-acid <2> Nickel-metal hydrate (NiMH) <3> Nickel-cadmium (NiCad) <4> Lithium <5> Carbon zinc <6> Zinc chloride <7> Alkaline <8> Rechargeable alkaline <9> Sodium sulphur (NaS) <10> Flow <99> Other HB + 1 Battery Bank #1 Nameplate Actual 2 0 2147483647 1 0 Watt-hrs DBAT WhMaxRtg ASG 2.6.2 Capacity Rating. The actual capacity or Amp- of the battery bank expressed in hrs Storage Capacity Units. HB + 2 Battery Bank #1 Effective Capacity. 2 0 2147483647 1 0 Watt-hrs DBAT EffWh ASG 2.6.2 The present actual capacity of the or Amp- battery bank expressed in Storage hrs Capacity Units. HB + 3 Battery Bank #1 Minimum Reserve for 2 0 1000 0.1 0 % DBAT UseWhMinPct ASG 2.6.2 Storage. As a percentage of the nominal useable storage (DBAT.CapWhUseRtg) HB + 4 Battery Bank #1 Maximum Reserve for 2 0 1000 0.1 0 % DBAT UseWhMaxPct ING 2.6.2 Storage. As a percentage of the nominal useable storage (DBAT.CapWhUseRtg). Expressed as a delta from the maximum effective capacity. HB + 5 Battery Bank #1 Battery State. 2 0 99 1 0 None DBAT BatSt ENS Enumeration: (list) <0> n/a, Unknown

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class <1> Disconnected <2> Initializing <3> Connected <4> Standby <5> SOC Protection <6> Suspending <99> Fault HB + 6 Battery Bank #1 Actual State of 3 0 1000 0.1 0 % DBAT SocWh ASG 2.6.2 Charge. Currently available energy in the battery, as a percentage of Effective Capacity. HB + 7 Battery Bank #1 State of Health. The 1 0 1000 0.1 0 % DBAT EffWhPct ASG ratio (expressed as a percentage) of the current rating of the battery with respect to the nameplate rating of the battery and end-of-life criteria. The rating of the battery may include one or more battery parameters that are selected as appropriate for the application and implementation. These parameters often include the energy capacity, but could also incorporate other measurements. HB + 8 Battery Bank #1 External Battery 3 0 2147483647 0.1 0 Volts DBAT ExtVol MV 2.4.1 Voltage. Voltage measured between battery charger and battery. HB + 9 Battery Bank #1 Internal Battery 3 0 2147483647 0.1 0 Volts DBAT IntnVol MV 2.4.1 Voltage. Internal voltage measurement. HB + 10 Battery Bank #1 Current 1 -2147483648 2147483647 0.1 0 Amps DBAT Amp MV 2.4.1 HB + 11 Battery Bank #1 Power 1 -2147483648 2147483647 0.1 0 Watts DBAT Watt MV 2.4.1 HB + 12 Battery Bank #1 Minimum Cell 1 0 2147483647 0.001 0 Volts SBAT CelVolLo MV 2.4.1 Voltage. Minimum cell voltage measurement of all cells in the bank. HB + 13 Battery Bank #1 Maximum Cell 1 0 2147483647 0.001 0 Volts SBAT CelVolHi MV 2.4.1 Voltage. Maximum cell voltage measurement of all cells in the bank. HB + 14 Battery Bank #1 Minimum 1 -200 200 0.1 0 Deg C SBAT CelTmpMin MV 2.4.1 Temperature. Minimum temperature

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class measurement for all sensors in the bank. HB + 15 Battery Bank #1 Maximum 1 -200 200 0.1 0 Deg C SBAT CelTmpMax MV 2.4.1 Temperature. Maximum temperature measurement for all sensors in the bank. HB + 16 Battery Bank #1 External Ambient 1 -200 200 0.1 0 Deg C DBAT ExtTmp MV 2.4.1 Temperature HB + 17 Battery Bank #1 Internal Ambient 1 -200 200 0.1 0 Deg C DBAT IntnTmp MV 2.4.1 Temperature HB + 18 Bat tery Bank #1 Charge Current Limit. 1 -2147483648 0 0.1 0 Amps DBAT ChaAmpLim MV 2.4.3 Instantaneous current limit on charging. HB + 19 Battery Bank #1 Discharge Current 1 0 2147483647 0.1 0 Amps DBAT DschAmpLim MV 2.4.3 Limit. Instantaneous current limit on discharging. HB + 20 Battery Bank #1 Minimum Voltage 1 0 2147483647 0.1 0 Volts DBAT VolMinLim MV 2.4.3 Limit. Instantaneous minimum voltage limit. HB + 21 Battery Bank #1 Maximum Voltage 1 0 2147483647 0.1 0 Volts DBAT VolMaxLim MV 2.4.3 Limit. Instantaneous maximum voltage limit. HB + 22 Battery Bank #1 Connected String 1 0 2147483647 1 0 n/a DBAT CelStrgCnt MV Count. Number of strings in the bank that are currently connected. HB + 23 Battery Bank #1 External Voltage - 2 0 2147483647 0.1 0 Volts DBAT ExtVolHiAls ASG 2.4.3 High Threshold HB + 24 Battery Bank #1 External Voltage - 2 0 2147483647 0.1 0 Volts DBAT ExtVolLoAls ASG 2.4.3 Low Threshold HB + 25 Battery Bank #1 Internal Voltage – 2 0 2147483647 0.1 0 Volts DBAT IntnVolHiAls ASG 2.4.3 High Threshold HB + 26 Battery Bank #1 Internal Voltage – 2 0 2147483647 0.1 0 Volts DBAT IntnVolLoAls ASG 2.4.3 Low Threshold . Battery Bank #2 . . . Battery Bank #b-1 . points . HB + bhai(b) Battery Bank #b Type of Storage 2 0 99 1 0 None DBAT BatTyp ENG

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class (list) Hb + bhai(b) Battery Bank #b Nameplate Actual 2 0 2147483647 1 0 Watt-hrs DBAT WhMaxRtg ASG 2.6.2 + 1 Capacity Rating. The actual total or Amp- capacity of the battery bank expressed hrs in Storage Capacity Units. Hb + bhai(b) Battery Bank #b Effective Capacity. 2 0 2147483647 1 0 Watt-hrs DBAT EffWh ASG 2.6.2 + 2 The present actual capacity of the or Amp- battery bank expressed in Storage hrs Capacity Units. Hb + bhai(b) Battery Bank #b Minimum Reserve for 2 0 1000 0.1 0 % DBAT UseWhMinPct ASG 2.6.2 + 3 Storage Hb + bhai(b) Battery Bank #b Maximum Reserve for 2 0 1000 0.1 0 % DBAT UseWhMaxPct ING 2.6.2 + 4 Storage. Hb + bhai(b) Battery Bank #b Battery State 2 0 99 1 0 None DBAT BatSt ENS + 5 (list) Hb + bhai(b) Battery Bank #b External Battery 3 0 2147483647 0.1 0 Volts DBAT SocWh ASG 2.4.1 + 6 Voltage Hb + bhai(b) Battery Bank #b Internal Battery 3 0 2147483647 0.1 0 Volts DBAT EffWhPct ASG 2.4.1 + 7 Voltage Hb + bhai(b) Battery Bank #b Actual State of 3 0 1000 0.1 0 % DBAT ExtVol MV 2.6.2 + 8 Charge Hb + bhai(b) Battery Bank #b State of Health 1 0 1000 0.1 0 % DBAT IntnVol MV 2.6.2 + 9 Hb + bhai(b) Battery Bank #b Current 1 -2147483648 2147483647 0.1 0 Amps DBAT Amp MV 2.4.1 + 10 Hb + bhai(b) Battery Bank #b Power 1 -2147483648 2147483647 0.1 0 Watts DBAT Watt MV 2.4.1 + 11 Hb + bhai(b) Battery Bank #b Minimum Cell Voltage 1 0 2147483647 0.001 0 Volts SBAT CelVolLo MV 2.4.3 + 12 Hb + bhai(b) Battery Bank #b Maximum Cell 1 0 2147483647 0.001 0 Volts SBAT CelVolHi MV 2.4.3 + 13 Voltage Hb + bhai(b) Battery Bank #b Minimum 1 -200 200 0.1 0 Deg C SBAT CelTmpMin MV 2.4.3 + 14 Temperature Hb + bhai(b) Battery Bank #b Maximum 1 -200 200 0.1 0 Deg C SBAT CelTmpMax MV 2.4.3 + 15 Temperature Hb + bhai(b) Battery Bank #b External Ambient 1 -200 200 0.1 0 Deg C DBAT ExtTmp MV 2.4.1 + 16 Temperature

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Def Transmitted Value Scaling Units IEC 61850 Point Refer Name / Description Evt Minimum Maximum Multi- Off- LN Index Data Object CDC To Cls plier set Class Hb + bhai(b) Battery Bank #b Internal Ambient 1 -200 200 0.1 0 Deg C DBAT IntnTmp MV 2.4.1 + 17 Temperature Hb + bhai(b) Battery Bank #b Charge Current Limit 1 -2147483648 0 0.1 0 Amps DBAT ChaAmpLim MV 2.4.3 + 18 Hb + bhai(b) Battery Bank #b Discharge Current 1 0 2147483647 0.1 0 Amps DBAT DschAmpLim MV 2.4.3 + 19 Limit Hb + bhai(b) Battery Bank #b Minimum Voltage 1 0 2147483647 0.1 0 Volts DBAT VolMinLim MV 2.4.3 + 20 Limit Hb + bhai(b) Battery Bank #b Maximum Voltage 1 0 2147483647 0.1 0 Volts DBAT VolMaxLim MV 2.4.3 + 21 Limit Hb + bhai(b) Battery Bank #b Connected String 1 0 2147483647 1 0 n/a DBAT CelStrgCnt MV 2.4.3 + 22 Count Hb + bhai(b) Battery Bank #b External Voltage - 2 0 2147483647 0.1 0 Volts DBAT ExtVolHiAls ASG 2.4.3 + 23 High Threshold Hb + bhai(b) Battery Bank #b External Voltage - 2 0 2147483647 0.1 0 Volts DBAT ExtVolLoAls ASG 2.4.3 + 24 Low Threshold Hb + bhai(b) Battery Bank #b Internal Voltage – 2 0 2147483647 0.1 0 Volts DBAT IntnVolHiAls ASG 2.4.3 + 25 High Threshold Hb + bhai(b) Battery Bank #b Internal Voltage – 2 0 2147483647 0.1 0 Volts DBAT IntnVolLoAls ASG 2.4.3 + 26 Low Threshold Vendor-Specific Analog Inputs

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Table 17 – Analog Input Protocol Options 3.5 ANALOG INPUT POINTS Static (Steady-State) Group Number: 30 Static Frozen Group Number: 31 Capabilities Event Group Number: 32 Frozen Analog Input Event Group Number: 33 Deadband Group Number: 34

3.5.1 Static Variation reported when variation 0 requested or in response to Class polls:  Variation 1 – 32-bit with flag  Variation 2 – 16-bit with flag  Variation 3 – 32-bit without flag  Variation 4 – 16-bit without flag  Variation 5 – single-precision floating point with flag  Variation 6 – double-precision floating point with flag  Based on point Index (add column to table in part 5)

3.5.2 Event Variation reported when variation 0 requested or in response to Class polls:  Variation 1 – 32-bit without time  Variation 2 – 16-bit without time Note: The support for analog input events can be determined remotely using protocol  Variation 3 – 32-bit with time object Group 0 Variation 231.  Variation 4 – 16-bit with time  Variation 5 – single-precision floating point w/o time  Variation 6 – double-precision floating point w/o time  Variation 7 – single-precision floating point with time  Variation 8 – double-precision floating point with time  Based on point Index (add column to table in part 5)

3.5.3 Event reporting mode:  A: Only most recent (value at time of event) When responding with event data and more than one event has occurred for a data point,  B: Only most recent (value at time of response) an Outstation may include all events or only the most recent event. Only the most recent event is typically reported for Analog Inputs. When reporting “only most recent”, the  C: All events analog value reported in the response may be the value at the time of the original event or • Based on point Index (add column to table in part 5) it may be the value at the time of the response.

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3.5 ANALOG INPUT POINTS Static (Steady-State) Group Number: 30 Static Frozen Group Number: 31 Capabilities Event Group Number: 32 Frozen Analog Input Event Group Number: 33 Deadband Group Number: 34

3.5.4 Analog Inputs Included in Class 0 response:  Always  Never  Only if the point is assigned to a class  Based on point Index (add column to table in part 5)

3.5.5 How Deadbands are set:  A. Global Fixed  B. Configurable through DNP  C. Configurable via other means  D. Other, explain ______ Based on point Index - column in part 5 specifies which of the options applies, B, C, or D

3.5.6 Analog Deadband Algorithm:  Simple • simple - just compares the difference from the previous reported value  Integrating • integrating - keeps track of the accumulated change  Other, explain ______• other - indicating another algorithm  Based on point Index (add column to table in part 5)

3.5.7 Static Frozen Analog Input Variation reported when variation 0 requested or in  Variation 1 – 32-bit with flag response to Class polls:  Variation 2 – 16-bit with flag  Variation 3 – 32-bit with time-of-freeze  Variation 4 – 16-bit with time-of-freeze  Variation 5 – 32-bit without flag  Variation 6 – 16-bit without flag  Variation 7 – Single-precision, floating-point with flag  Variation 8 – Double-precision, floating-point with flag  Based on point Index (add column to table in part 5)

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3.5 ANALOG INPUT POINTS Static (Steady-State) Group Number: 30 Static Frozen Group Number: 31 Capabilities Event Group Number: 32 Frozen Analog Input Event Group Number: 33 Deadband Group Number: 34

3.5.8 Frozen Analog Input Event Variation reported when variation 0 requested or in  Variation 1 – 32-bit without time response to Class polls:  Variation 2 – 16-bit without time

 Variation 3 – 32-bit with time Note: The support for frozen analog input events can be determined remotely using protocol object Group 0 Variation 230.  Variation 4 – 16-bit with time  Variation 5 – Single-precision, floating-point without time  Variation 6 – Double-precision, floating-point without time  Variation 7 – Single-precision, floating-point with time  Variation 8 – Double-precision, floating-point with time  Based on point Index (add column to table in part 5)

3.5.9 Frozen Analog Inputs included in Class 0 response:  Always  Never  Only if point is assigned to Class 1, 2, or 3  Based on point Index (add column to table in part 5)

3.5.10 Frozen Analog Input Event reporting mode:  A: Only most recent frozen value When responding with event data and more than one event has occurred for a data point,  B: All frozen values an Outstation may include all events or only the most recent event. All events are typically reported for Frozen Analog Inputs.  Based on point Index (add column to table in part 5)

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3.5 ANALOG INPUT POINTS Static (Steady-State) Group Number: 30 Static Frozen Group Number: 31 Capabilities Event Group Number: 32 Frozen Analog Input Event Group Number: 33 Deadband Group Number: 34

3.5.11 Analog Inputs Event Buffer Organization:  Fixed at ______When event buffers are allocated per object group (see part 1.7.6), indicate the number of  Configurable, range ______to ______events that can be buffered for Analog Inputs. If event buffers are not allocated per object group then set “Fixed at 0”.  Configurable, selectable from ____,____,____  Configurable, other, describe______

3.5.12 Frozen Analog Inputs Event Buffer Organization:  Fixed at ______When event buffers are allocated per object group (see part 1.7.6), indicate the number of  Configurable, range ______to ______events that can be buffered for Frozen Analog Inputs. If event buffers are not allocated per object group then set “Fixed at 0”.  Configurable, selectable from ____,____,____  Configurable, other, describe______

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2.2.9 Analog Outputs Table 19 lists the analog output points to be used in the DNP3 Profile for DERs. Table 22 specifies the options to be used by outstations when processing and reporting these points. Note that support for floating point analog output objects is not required by this specification because they are not DNP3-L2 objects. However, the use of these object variations by agreement between the master and outstation is highly recommended. Floating-point quantities are not scaled by the outstation; they are transmitted in the units specified in Table 19. For instance, 1kW is transmitted as 1.0E+3 Watts. Regardless of whether floating point is implemented, per the rules of DNP3, any device that supports floating-point objects must also support integer analog output objects. The “Transmitted Value”, “Scaling” and “Resolution” columns refer to the situation when integers are used. The integer value is to be sent with as little scaling as possible, as specified in Table 19. Only those values typically measured in fractions of an integer (power factor, percent, etc.) shall be scaled. This means that for some functions, the master may need to request or transmit 32-bit analog output object variations in order to transmit the data as integers without overflow; e.g. a 50kW real power output cannot be represented with a 16-bit value because it would exceed 32767 Watts. Note that 32-bit analog outputs require an implementation that goes beyond DNP3 Subset Level 2. This profile includes a set of analog output points that provide a “generic curve” definition used by several different inverter functions. The units and scaling of these points depends on the context in which they are used, as described in Table 20 and Table 21 on page 168. If floating point analog outputs are not used, the master and outstation are expected to use these scaling parameters. The Device Profile document for the outstation should not just copy the 32-bit minimum and maximum values shown here, but show the actual maximum and minimum values for the system. Because the actual minimum and maximum of some quantities vary from system to system, a “Resolution” column is not included in this profile. Instead, please note that a 1% resolution from the nominal value is preferred. Note that analog output event objects are not required. In most cases, there is a corresponding analog input value to provide feedback when an analog output has been changed. Table 18 illustrates in the standard DNP Device profile format the control operations that shall be supported for every analog output point (these columns are not shown in Table 19 because of lack of space and because they are the same for all analog output points.)

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Table 18 – Required Control Operations for Analog Outputs

Supported Control Operations

No Ack No

Select/Operate DirectOperate DirectOperate – X X X

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Table 19 - Analog Output Points List Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class

System Analog Outputs

0 2147483647 0.1 0 Volts DECP VRef ASG 2.10.4 AO0 Reference Voltage

-2147483648 2147483647 0.1 0 Volts DECP VRefOfs ASG 2.10.4 AO1 Reference Voltage Offset

0 70000 0.001 0 Hz DECP EcpNomHz ASG 2.10.4 AO2 Nominal Grid Frequency

Open Loop Response Time 0 1000 0.1 0 Percent DSTO OpnLoopPct 2.3.4 Percentage. Percent of target to AO3 reach within the open loop response time. Default is 90%. Power Factor Sign convention: 1 2 1 0 None MMXU PFSign ENG 2.7 AO4 <1> IEC – active power <2> IEEE – lead/lag Reference for Reactive Power 0 3 1 0 None DSTO VArRef ENG 2.7 Setpoints. Selects which setpoint (list) is active. Default is <3>. <0> Not applicable / Unknown <1> Percent of Maximum Active AO5 Power (WMax) <2> Percent of Maximum Reactive Power (VArMax) <3> Percent of Available Reactive Power (VArAval) DER Start (Return to Service) 0 20000 0.01 0 Percent DCTE VHiLim ASG 2.4.5 AO6 Voltage High Limit. Percent of Reference Voltage. DER Start (Return to Service) 0 10000 0.01 0 Percent DCTE VLoLim ASG 2.4.5 AO7 Voltage Low Limit. Percent of Reference Voltage. DER Start (Return to Service) 0 70000 0.001 0 Hz DCTE HzHiLim ASG 2.4.5 AO8 Frequency High Limit

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class DER Start (Return to Service) 0 70000 0.001 0 Hz DCTE HzLoLim ASG 2.4.5 AO9 Frequency Low Limit DER Start (Return to Service) 0 2147483647 1 0 Seconds DCTE RtnSrvDlyTim ING 2.4.5 AO10 Delay DER Start (Return to Service) 0 2147483647 1 0 Seconds DCTE WinTms ING 2.4.5 AO11 Time Window DER Start (Return to Service) 0 2147483647 1 0 Seconds DCTE RtnSrvRmpTim ING 2.4.5 AO12 Ramp Up Time DER Stop (Cease to 0 2147483647 1 0 Seconds DCTE WinTms ING 2.4.5 AO13 Energize)Time Window DER Stop (Cease to Energize) 0 2147483647 1 0 Seconds DCTE RmpTms ING 2.4.5 AO14 Ramp Down Time DER Stop (Cease to Energize) 0 2147483647 1 0 Seconds DCTE RvrtTms ING 2.4.5 Reversion Timeout Period. Time AO15 to revert from the stopped state and return to service. Connect/Disconnect Time 0 2147483647 1 0 Seconds DCTE WinTms ING 2.4.4 AO16 Window Connect/Disconnect Reversion 0 2147483647 1 0 Seconds DCTE RvrtTms ING 2.4.4 Timeout Period . Timeout AO17 (reversion time is for the Disconnect only)

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class Requested Settings Group 0 255 1 0 None DECP EcpIsldSt ENG 2.11 <0> Not Used (list) <1> Unspecified / Autonomously Determined (see BO Enable Sensed Grid Config Detection) <2> Factory Configuration <3> Default Configuration / Comms Lost <4> Normal Grid-Connected Configuration <5> Islanded Condition 1 AO18 (small, local island) <6> Islanded Condition 2 (larger, area island) <7> Islanded Condition 3 (largest, regional island) <8> 1st Alternate Grid- Connected Configuration <9> 2nd Alternate Grid- Connected Configuration <10> 3rd Alternate Grid- Connected Configuration <11-255> Reserved for future assignment

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class Settings Group Being Edited 0 255 1 0 None DRCC EcpIsldSt ENG 2.11 <0> Not Used (list) <1> Unspecified / Autonomously Determined (see BO Enable Sensed Grid Config Detection) <2> Factory Configuration <3> Default Configuration / Comms Lost <4> Normal Grid-Connected Configuration <5> Islanded Condition 1 AO19 (small, local island) <6> Islanded Condition 2 (larger, area island) <7> Islanded Condition 3 (largest, regional island) <8> 1st Alternate Grid- Connected Configuration <9> 2nd Alternate Grid- Connected Configuration <10> 3rd Alternate Grid- Connected Configuration <11-255> Reserved for future assignment Freeze Counter Interval. Interval 0 2147483647 1 0 n/a ------2.2.7 between freeze counter operations after the initial AO20 occurrence. A zero value means the free counter operation is not repeated. Freeze Counter Interval Units. 0 9 1 0 None ------2.2.7 Units of the interval between (list) AO21 freeze counter operations. See reference section.

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class Low/High Voltage Ride-Through 0 2147483647 1 0 n/a DHVT EcpRef 16 ORG 2.5.1 Signal Meter ID. Referenced AO22 ECP. This is the meter from which current is being read to evaluate and provide support. Low/High Voltage Ride-Through 0 2147483647 1 0 n/a PTOV BlkRef ORG 2.5.1 High Must Trip Curve Index. AO23 Index of the Voltage Ride-through curve which specifies trip points when the voltage is high. Low/High Voltage Ride-Through 0 2147483647 1 0 n/a PTUV BlkRef ORG 2.5.1 Low Must Trip Curve Index. Index AO24 of the Voltage Ride-through curve which specifies trip points when the voltage is low. Low/High Voltage Ride-Through 0 2147483647 1 0 n/a PTOV BlkRef ORG 2.5.1 High Momentary CessationTrip Curve Index. Index of the Voltage AO25 Ride-through curve which specifies where generation/ discharging must stop when the voltage is high. Low/High Voltage Ride-Through 0 2147483647 1 0 n/a PTUV BlkRef ORG 2.5.1 Low Must Trip Curve Index. Index of the Voltage Ride-through curve AO26 which specifies Where generation/ discharging must stop when the voltage is low. Low/High Frequency Ride- 0 2147483647 1 0 n/a DHFT EcpRef 17 ORG 2.5.2 Through Signal Meter ID. Referenced ECP. This is the AO27 meter from which current is being read to evaluate and provide support.

16 DHVT.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXN.Vol 17 DHFT.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.Hz

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class Low/High Frequency Ride- 0 2147483647 1 0 n/a PTOF BlkRef ORG 2.5.2 Through High Must Trip Curve Index. Index of the Frequency AO28 Ride-through curve which specifies trip points when the frequency is high. Low/High Frequency Ride- 0 2147483647 1 0 n/a PTUF BlkRef ORG 2.5.2 Through Low Must Trip Curve Index. Index of the Frequency AO29 Ride-through curve which specifies trip points when the frequency is low. Low/High Frequency Ride- 0 2147483647 1 0 n/a PTOF BlkRef ORG 2.5.2 Through High Momentary Cessation Curve Index. Index of AO30 the Frequency Ride-through curve which specifies where generation/ discharging must stop when the frequency is high. Low/High Frequency Ride- 0 2147483647 1 0 n/a PTUF BlkRef ORG 2.5.2 Through Low Momentary Cessation Curve Index. Index of AO31 the Frequency Ride-through curve which specifies where generation/ discharging must stop when the frequency is low. Dynamic Reactive Current 0 number of 1 0 n/a DRGS ModPrio ING 2.10.4 AO32 Support Mode Priority modes Dynamic Reactive Current 0 2147483647 1 0 Seconds DRGS WinTms ING 2.3.2 AO33 Support Enabling Time Window Dynamic Reactive Current 0 2147483647 1 0 Seconds DRGS RmpTms ING 2.3.2 AO34 Support Enabling Ramp Time Dynamic Reactive Current 0 2147483647 1 0 Seconds DRGS RvrtTms ING 2.3.2 AO35 Support Reversion Timeout Period

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class

Dynamic Reactive Current 0 2147483647 1 0 n/a DRGS EcpRef 18 ORG 2.5.3 AO36 Support Signal Meter ID Dynamic Reactive Current 0 2 1 0 None DRGS ArGraMod ENG 2.5.3 Support - Gradient Mode. (list) <0> Undefined AO37 <1> Gradients reach 0 at the moving average Voltage <2> Gradients reach 0 at the Voltage deadbands Dynamic Reactive Current -10000 0 0.1 0 Percent DRGS DbVMin ASG 2.5.3 Support Deadband Minimum Voltage. Percentage of the nominal voltage (DRCT.Vref), AO38 measured from the moving average voltage (RDGS.VAv). Support is no longer applied when the voltage stays above this value for the length of the Hold Time. Dynamic Reactive Current 0 10000 0.1 0 Percent DRGS DbVMax ASG 2.5.3 Support Deadband Maximum Voltage. Percentage of the nominal voltage (DRCT.Vref), AO39 measured from the moving average voltage (RDGS.VAv). Support is no longer applied when the voltage stays below this value for the length of the Hold Time. Dynamic Reactive Current -2147483648 2147483647 0.001 0 Percent DRGS ArGraSag ASG 2.5.3 Support Gradient for Sags. current Percentage of the rated current to per apply capacitively per percentage percent AO40 of the negative deviation from the voltage moving average voltage deviation (RDGS.Av). It is a ratio of percent and is therefore unitless.

18 DRGS.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXN.Vol

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class Dynamic Reactive Current -2147483648 2147483647 0.001 0 Percent DRGS ArGraSwl ASG 2.5.3 Support Gradient for Swells. current Percentage of the rated current per (DRAT.ARtg) to apply inductively percent AO41 per percentage of the positive voltage deviation from the moving deviation average voltage (RDGS.Av). It is a ratio of percent and is therefore unitless. Dynamic Reactive Current 0 2147483647 1 0 Seconds DRGS FilTms ING 2.5.3 Support Filter Time for Moving AO42 Average Voltage (RDGS.VAv). Used to determine amount of dynamic reactive current support. Dynamic Reactive Current 0 1000 0.1 0 Percent DRGS BlkZnV ASG 2.5.3 Support Block Zone Voltage. Percentage of the nominal voltage AO43 (DRCT.VRef) below which no reactive current support shall be applied. Dynamic Reactive Current 0 1000 0.1 0 Percent DRGS HysBlkZnV ASG 2.5.3 Support Hysteresis Block Zone Voltage. Percentage of the nominal voltage (DRCT.VRef). AO44 After being blocked, reactive current support shall not resume until the voltage has been above BlkZnV + HysBlkZnV. Dynamic Reactive Current 0 2147483647 1 0 ms DRGS BlkZnTmms ING 2.5.3 Support Block Zone Time. Time in milliseconds from the beginning AO45 of any "sag" event, before which dynamic reactive current support will always continue, regardless of how low voltage may sag.

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class Dynamic Reactive Current 0 2147483647 1 0 ms DRGS StrHoldTmms ING 2.5.3 Support Start Hold Time. When the voltage exceeds the deadband limits for this length of AO46 time (measured in milliseconds), the “sag” or “swell” event begins and the DER may begin altering active power output. Dynamic Reactive Current 0 2147483647 1 0 ms DRGS EndHoldTmms ING 2.5.3 Support End Hold Time. When the voltage returns to within the deadband limits for this length of time (measured in milliseconds), AO47 the "sag" or "swell" event is considered to be over. Reactive current support ends, frozen values are unfrozen, and a new event can begin. 0 number of 1 0 n/a DVWD ModPrio ING 2.10.4 AO48 Dynamic Volt-Watt Mode Priority modes Dynamic Volt-Watt Enabling Time 0 2147483647 1 0 Seconds DVWD WinTms ING 2.3.2 AO49 Window Dynamic Volt-Watt Enabling 0 2147483647 1 0 Seconds DVWD RmpTms ING 2.3.2 AO50 Ramp Time Dynamic Volt-Watt Reversion 0 2147483647 1 0 Seconds DVWD RvrtTms ING 2.3.2 AO51 Timeout period Dynamic Volt-Watt Signal Meter 0 2147483647 1 0 n/a DVWD EcpRef 19 ORG 2.5.5 AO52 ID Dynamic Volt-Watt Gradient. -2147483648 2147483647 0.001 0 Percent DVWD DynVWGra ASG 2.5.5 Signed unit-less quantity that watts per establishes the ratio of additional percent AO53 Watts supplied (expressed in voltage terms of % DRCT.WMax) to the differenc present difference from the e

19 DVWD.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXN.Vol

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class moving average voltage (expressed as % DRCT.VRef).

Dynamic Volt-Watt Filter Time. 0 2147483647 1 0 Seconds DVWD VWFilTms ASG 2.5.5 The time in seconds used to AO54 calculate the moving average voltage for dynamic Volt-Watt support. Dynamic Volt-Watt Lower 0 1000 0.1 0 Percent DVWD DbVWLo ASG 2.5.5 Deadband. Percentage of the nominal voltage (DRCT.Vref) AO55 measured below the moving average voltage. If the present voltage is above this value, no additional Watts shall be supplied. Dynamic Volt-Watt Upper 0 1000 0.1 0 Percent DVWD DbVWHi ASG 2.5.5 Deadband. Percentage of the nominal voltage (DRCT.Vref) AO56 measured above the moving average voltage. If the present voltage is below this value, no additional Watts shall be supplied. 0 number of 1 0 n/a DHFW ModPrio ING 2.10.4 AO57 Frequency-Watt Mode Priority modes Frequency-Watt Enabling Time 0 2147483647 1 0 Seconds DHFW WinTms ING 2.3.2 AO58 Window Frequency-Watt Enabling Ramp 0 2147483647 1 0 Seconds DHFW RmpTms ING 2.3.2 AO59 Time Frequency-Watt Reversion 0 2147483647 1 0 Seconds DHFW RvrtTms ING 2.3.2 AO60 Timeout Period

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 0 2147483647 1 0 n/a DHFW EcpRef 20 ORG 2.5.3 AO61 Frequency-Watt Signal Meter ID

Frequency-Watt High Starting 0 70000 0.001 0 Hz DHFW HzStr ASG 2.5.3 AO62 Frequency Frequency-Watt High Stopping 0 70000 0.001 0 Hz DHFW HzStop ASG 2.5.3 AO63 Frequency -2147483648 2147483647 0.001 0 % Watts DHFW WGra ASG per % Hz Frequency-Watt High Discharging AO64 diff / Generating Gradient

-2147483648 2147483647 0.001 0 % Watts DHFW WChaGra ASG per % Hz Frequency-Watt High Charging AO65 diff Gradient

Frequency-Watt Low Starting -70000 0 0.001 0 Hz DLFW HzStr ASG 2.5.3 AO66 Frequency Frequency-Watt Low Stopping -70000 0 0.001 0 Hz DLFW HzStop ASG 2.5.3 AO67 Frequency -2147483648 2147483647 0.001 0 % Watts DLFW WGra ASG 2.5.3 per % Hz Frequency-Watt Low Discharging AO68 diff / Generating Gradient

-2147483648 2147483647 0.001 0 % Watts DLFW WChaGra ASG 2.5.3 per % Hz Frequency-Watt Low Charging AO69 diff Gradient

20 DHFW.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.Hz

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 0 2147483647 1 0 Millisec DHFW ActStrDlTmms ING 2.5.3 AO70 Frequency-Watt Start Delay

0 2147483647 1 0 Millisec DHFW ActStopDlTmms ING 2.5.3 AO71 Frequency-Watt Stop Delay

Frequency-Watt Time Constant 0 2147483647 1 0 Seconds DHFW OpnLoop ING 2.3.4 AO72 Ramp Up Time Frequency-Watt Time Constant 0 2147483647 1 0 Seconds DHFW OpnLoop ING 2.3.4 AO73 Ramp Down Time 0 500000 0.1 0 Percent DHFW DschRpuRte ASG 2.3.4 Frequency-Watt Discharge Ramp AO74 per Up Rate Second 0 500000 0.1 0 Percent DHFW DschRpdRte ASG 2.3.4 Frequency-Watt Discharge Ramp AO75 per Down Rate Second 0 500000 0.1 0 Percent DHFW ChaRpuRte ASG 2.3.4 Frequency-Watt Charge Ramp Up AO76 per Rate Second 0 500000 0.1 0 Percent DHFW ChaRpdRte ASG 2.3.4 Frequency-Watt Charge Ramp AO77 per Down Rate Second -2147483648 2147483647 0.001 0 % Watts DHFW RtnRmpRte ASG 2.5.3 Frequency-Watt High Return AO78 per % Hz Gradient diff -2147483648 2147483647 0.001 0 % Watts DLFW RtnRmpRte ASG 2.5.3 Frequency-Watt Low Return AO79 per % Hz Gradient diff Frequency-Watt Minimum Usable 0 1000 0.1 0 Percent DHFW SocUseMin ING 2.6.5 AO80 SOC Frequency-Watt Maximum Usable 0 1000 0.1 0 Percent DHFW SocUseMax ING 2.6.5 AO81 SOC 0 number of 1 0 n/a DWMX ModPrio ING 2.10.4 AO82 Active Power Limit Mode Priority modes Active Power Limit Enabling Time 0 2147483647 1 0 Seconds DWMX WinTms ING 2.3.2 AO83 Window

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class

Active Power Limit Enabling 0 2147483647 1 0 Seconds DWMX RmpTms ING 2.3.2 AO84 Ramp Time Active Power Limit Reversion 0 2147483647 1 0 Seconds DWMX RvrtTms ING 2.3.2 AO85 Timeout Period Active Power Limit Signal Meter 0 2147483647 1 0 n/a DWMX EcpRef 21 ORG 2.6.1 AO86 ID Active Power Limit Charge 0 1000 0.1 0 Percent DWMX WLimPct ASG 2.6.1 Setpoint. Maximum allowed Watts AO87 as a percentage of Maximum Active Power capability. Active Power Limit Generation 0 1000 0.1 0 Percent DWMN WLimPct ASG 2.6.1 Setpoint. Maximum allowed Watts AO88 as a percentage of Maximum Active Power capability. 0 number of 1 0 n/a DWGC ModPrio ING 2.10.4 AO89 Charge/Discharge Mode Priority modes Charge/Discharge Enabling Time 0 2147483647 1 0 Seconds DWGC WinTms ING 2.3.2 AO90 Window Charge/Discharge Enabling Ramp 0 2147483647 1 0 Seconds DWGC RmpTms ING 2.3.2 AO91 Time Charge/Discharge Reversion 0 2147483647 1 0 Seconds DWGC RvrtTms ING 2.3.2 AO92 Timeout Period Charge/Discharge Active Power -1000 1000 0.1 0 Percent DWGC GnWPctSpt ASG 2.6.2 AO93 Target. Percentage of maxmum active power. Charge/Discharge Time Constant 0 2147483647 1 0 Seconds DWGC OpnLoop ING 2.3.4 AO94 Ramp Up Time Charge/Discharge Time Constant 0 2147483647 1 0 Seconds DWGC OpnLoop ING 2.3.4 AO95 Ramp Down Time 0 500000 0.1 0 Percent DWGC DschRpuRte ASG 2.3.4 Charge/Discharge Discharge AO96 per Ramp Up Rate Second

21 DWMX.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 0 500000 0.1 0 Percent DWGC DschRpdRte ASG 2.3.4 Charge/Discharge Discharge AO97 per Ramp Down Rate Second 0 500000 0.1 0 Percent DWGC ChaRpuRte ASG 2.3.4 Charge/Discharge Charge Ramp AO98 per Up Rate Second 0 500000 0.1 0 Percent DWGC ChaRpdRte ASG 2.3.4 Charge/Discharge Charge Ramp AO99 per Down Rate Second Charge/Discharge Minimum -1000 1000 0.1 0 Percent DWGC SocUseMinPct ASG 2.6.2 Reserve for Storage. The minimum level to which the AO100 storage system may be discharged, expressed as a percentage of the total usable storage. Charge/Discharge Maximum -1000 1000 0.1 0 Percent DWGC SocUseMaxPct ASG 2.6.2 Reserve for Storage. The maximum level to which the AO101 storage system may be discharged, expressed as a percentage of the total usable storage. Coordinated Charge/Discharge 0 number of 1 0 n/a DTCD ModPrio ING 2.10.4 AO102 Mode Priority modes Coordinated Charge/Discharge 0 2147483647 1 0 Seconds DTCD WinTms ING 2.3.2 AO103 Enabling Time Window Coordinated Charge/Discharge 0 2147483647 1 0 Seconds DTCD RmpTms ING 2.3.2 AO104 Enabling Ramp Time Coordinated Charge/Discharge 0 2147483647 1 0 Seconds DTCD RvrtTms ING 2.3.2 AO105 Reversion Timeout Period Coordinated Charge/Discharge 0 1000 0.1 0 Percent DTCD SocUseTgtPct ASG 2.6.3 Target State of Charge. Charge AO106 that the system is expected to achieve, as a percentage of the

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class usable capacity.

Coordinated Charge/Discharge 0 2147483647 1 0 Days DTCD DateTgt ING 2.6.3 Target Date. Date by which the storage system must reach the AO107 target SOC. Expressed as number of days since January 1, 1970, UTC. Coordinated Charge/Discharge 0 2147483647 1 0 Milli- DTCD DateTgtTms ING 2.6.3 Target Time. Time by which seconds storage system must reach the AO108 target SOC. Expressed as number of milliseconds since the start of Target Date. Coordinated Charge/Discharge 0 2147483647 1 0 Watt- DTCD SocWReq ING 2.6.3 AO109 Energy Request hours Coordinated Charge/Discharge 0 2147483647 1 0 Seconds DTCD ChaDurTms ING 2.6.3 AO110 Minimum Charging Duration Coordinated Charge/Discharge 0 2147483647 1 0 Days DTCD DateTgt ING 2.6.3 AO111 Date of Reference Coordinated Charge/Discharge 0 2147483647 1 0 Milli- DTCD SocDateTms ING 2.6.3 AO112 Time of Reference seconds Coordinated Charge/Discharge 0 2147483647 1 0 Seconds DTCD ChaDurMax ING 2.6.3 AO113 Duration at Maximum Charge Rate Coordinated Charge/Discharge 0 2147483647 1 0 Seconds DTCD DschDurMax ING 2.6.3 AO114 Duration at Maximum Discharge Rate Active Power Response Mode #1 0 number of 1 0 n/a DPKP ModPrio ING 2.10.4 AO115 Priority modes Active Power Response Mode #1 0 2147483647 1 0 Seconds DPKP WinTms ING 2.3.2 AO116 Enabling Time Window Active Power Response Mode #1 0 2147483647 1 0 Seconds DPKP RmpTms ING 2.3.2 AO117 Enabling Ramp Time

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class

Active Power Response Mode #1 0 2147483647 1 0 Seconds DPKP RvrtTms ING 2.3.2 AO118 Reversion Timeout Period Active Power Response Mode #1 0 2147483647 1 0 n/a DPKP EcpRef 22 ORG 2.6.4.1 AO119 Signal Meter ID 2.6.4.2 Active Power Response Mode #1 -2147483648 2147483647 1 0 Watts DPKP PkPwrWLim ASG 2.6.4.1 AO120 Power Threshold 2.6.4.2 Active Power Response Mode #1 0 1000 0.1 0 Percent DPKP PkPwrFolPct ING 2.6.4.1 AO121 Ratio 2.6.4.2 0 500000 0.1 0 Percent DPKP RpuRte ASG 2.3.4 Active Power Response Mode #1 AO122 per Ramp Up Rate Second 0 500000 0.1 0 Percent DPKP RpdRte ASG 2.3.4 Active Power Response Mode #1 AO123 per Ramp Down Rate Second Active Power Response Mode #2 0 number of 1 0 n/a DGFL ModPrio ING 2.10.4 AO124 Priority modes Active Power Response Mode #2 0 2147483647 1 0 Seconds DGFL WinTms ING 2.3.2 AO125 Enabling Time Window Active Power Response Mode #2 0 2147483647 1 0 Seconds DGFL RmpTms ING 2.3.2 AO126 Enabling Ramp Time Active Power Response Mode #2 0 2147483647 1 0 Seconds DGFL RvrtTms ING 2.3.2 AO127 Reversion Timeout Period Active Power Response Mode #2 0 2147483647 1 0 n/a DGFL EcpRef 23 ORG 2.6.4.1 AO128 Signal Meter ID 2.6.4.2 Active Power Response Mode #2 -2147483648 2147483647 1 0 Watts DGFL PkPwrWLim ASG 2.6.4.1 AO129 Power Threshold 2.6.4.2 Active Power Response Mode #2 0 1000 0.1 0 Percent DGFL PkPwrFolPct ING 2.6.4.1 AO130 Ratio 2.6.4.2

22 DPKPEcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW 23 DGFL.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 0 500000 0.1 0 Percent DGFL RpuRte ASG 2.3.4 Active Power Response Mode #2 AO131 per Ramp Up Rate Second 0 500000 0.1 0 Percent DGFL RpdRte ASG 2.3.4 Active Power Response Mode #2 AO132 per Ramp Down Rate Second Active Power Response Mode #3 0 number of 1 0 n/a DLFL ModPrio ING 2.10.4 AO133 Priority modes Active Power Response Mode #3 0 2147483647 1 0 Seconds DLFL WinTms ING 2.3.2 AO134 Enabling Time Window Active Power Response Mode #3 0 2147483647 1 0 Seconds DLFL RmpTms ING 2.3.2 AO135 Enabling Ramp Time Active Power Response Mode #3 0 2147483647 1 0 Seconds DLFL RvrtTms ING 2.3.2 AO136 Reversion Timeout Period Active Power Response Mode #3 0 2147483647 1 0 n/a DLFL EcpRef 24 ORG 2.6.4.1 AO137 Signal Meter ID 2.6.4.2 Active Power Response Mode #3 -2147483648 2147483647 1 0 Watts DLFL PkPwrWLim ASG 2.6.4.1 AO138 Power Threshold 2.6.4.2 Active Power Response Mode #3 0 1000 0.1 0 Percent DLFL PkPwrFolPct ING 2.6.4.1 AO139 Ratio 2.6.4.2 0 500000 0.1 0 Percent DLFL RpuRte ASG 2.3.4 Active Power Response Mode #3 AO140 per Ramp Up Rate Second 0 500000 0.1 0 Percent DLFL RpdRte ASG 2.3.4 Active Power Response Mode #3 AO141 per Ramp Down Rate Second 0 number of 1 0 n/a DAGC ModPrio ING 2.10.4 AO142 AGC Mode Priority modes 0 2147483647 1 0 Seconds DAGC WinTms ING 2.3.2 AO143 AGC Enabling Time Window

24 DLFL.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 0 2147483647 1 0 Seconds DAGC RmpTms ING 2.3.2 AO144 AGC Enabling Ramp Time

0 2147483647 1 0 Seconds DAGC RvrtTms ING 2.3.2 AO145 AGC Reversion Timeout Period

-2147483648 2147483647 1 0 Watts DAGC GnWSpt ASG 2.6.5 AO146 AGC Active Power Target

AGC Ramp Time Constant Up 0 2147483647 1 0 Seconds DAGC OpnLoop ING 2.6.5 AO147 Time AGC Ramp Time Constant Down 0 2147483647 1 0 Seconds DAGC OpnLoop ING 2.6.5 AO148 Time 0 500000 0.1 0 Percent DAGC DschRpuRte ASG 2.3.4 AO149 AGC Discharge Ramp Up Rate per Second 0 500000 0.1 0 Percent DAGC DschRpdRte ASG 2.3.4 AO150 AGC Discharge Ramp Down Rate per Second 0 500000 0.1 0 Percent DAGC ChaRpuRte ASG 2.3.4 AO151 AGC Charge Ramp Up Rate per Second 0 500000 0.1 0 Percent DAGC ChaRpdRte ASG 2.3.4 AO152 AGC Charge Ramp Down Rate per Second 0 1000 0.1 0 Percent DAGC SocUseMinPct ING 2.6.5 AO153 AGC Minimum Usable SOC

0 1000 0.1 0 Percent DAGC SocUseMaxPct ING 2.6.5 AO154 AGC Maximum Usable SOC

Active Power Smoothing Mode 0 number of 1 0 n/a DWSM ModPrio ING 2.10.4 AO155 Priority modes Active Power Smoothing Enabling 0 2147483647 1 0 Seconds DWSM WinTms ING 2.3.2 AO156 Time Window Active Power Smoothing Enabling 0 2147483647 1 0 Seconds DWSM RmpTms ING 2.3.2 AO157 Ramp Time

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class

Active Power Smoothing 0 2147483647 1 0 Seconds DWSM RvrtTms ING 2.3.2 AO158 Reversion Timeout Period Active Power Smoothing Signal 0 2147483647 1 0 n/a DWSM EcpRef 25 ORG 2.6.6 AO159 Meter ID -2147483648 2147483647 0.001 0 Watts per DWSM WSmthGra ASG 2.6.6 AO160 Active Power Smoothing Gradient delta- watt Active Power Smoothing Lower -2147483648 0 1 0 Watts DWSM WSmthLoLim ASG 2.6.6 Limit. Difference in Watts from the moving average of the reference AO161 power (MMXN1.Watt) above which no smoothing shall be applied. Active Power Smoothing Upper 0 2147483647 1 0 Watts DWSM WSmthHiLim ASG 2.6.6 Limit. Difference in Watts from the AO162 moving average of the reference power (MMXN.Watt) below which no smoothing shall be applied. Active Power Smoothing Filter 0 2147483647 1 0 Seconds DWSM FilTms ING 2.6.6 Time (Seconds). Time in seconds used to calculate the moving AO163 average of the reference load or generation (MMXN1.Watt) being smoothed. 0 500000 0.1 0 Percent DWSM RpuRte ASG 2.3.4 Active Power Smoothing AO164 per Discharge Ramp Up Rate Second 0 500000 0.1 0 Percent DWSM RpdRte ASG 2.3.4 Active Power Smoothing AO165 per Discharge Ramp Down Rate Second 0 500000 0.1 0 Percent DWSM RpuChaRte ASG 2.3.4 Active Power Smoothing Charge AO166 per Ramp Up Rate Second

25 DWSM.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 0 500000 0.1 0 Percent DWSM RpdChaRte ASG 2.3.4 Active Power Smoothing Charge AO167 per Ramp Down Rate Second 0 number of 1 0 n/a DVWC ModPrio ING 2.10.4 AO168 Volt-Watt Mode Priority modes 0 2147483647 1 0 Seconds DVWC WinTms ING 2.3.2 AO169 Volt-Watt Enabling Time Window

0 2147483647 1 0 Seconds DVWC RmpTms ING 2.3.2 AO170 Volt-Watt Enabling Ramp Time

Volt-Watt Reversion Timeout 0 2147483647 1 0 Seconds DVWC RvrtTms ING 2.3.2 AO171 Period 0 2147483647 1 0 n/a DVWC EcpRef 26 ORG 2.6.7 AO172 Volt-Watt Signal Meter ID

0 2147483647 1 0 n/a DVWC VWCrv CSG 2.6.7 AO173 Volt-Watt Curve Index

0 2147483647 1 0 Seconds DVWC FilTms ING 2.6.7 AO174 Volt-Watt Filter Time (Seconds)

Volt-Watt Ramp Up Time 0 2147483647 1 0 Seconds DVWC OpnLoop ING 2.3.4 AO175 Constant Volt-Watt Ramp Down Time 0 2147483647 1 0 Seconds DVWC OpnLoop ING 2.3.4 AO176 Constant 0 500000 0.1 0 Percent DVWC DschRpuRte ASG 2.3.4 Volt-Watt Discharging Ramp Up AO177 per Rate Second 0 500000 0.1 0 Percent DVWC DschRpdRte ASG 2.3.4 Volt-Watt Discharging Ramp AO178 per Down Rate Second 0 500000 0.1 0 Percent DVWC ChaRpuRte ASG 2.3.4 Volt-Watt Charging Ramp Up AO179 per Rate Second

26 DVWC.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXN.Vol

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 0 500000 0.1 0 Percent DVWC ChaRpdRte ASG 2.3.4 Volt-Watt Charging Ramp Down AO180 per Rate Second Frequency-Watt Curve Mode 0 number of 1 0 n/a DHFW ModPrio ING 2.10.4 AO181 Priority modes Frequency-Watt Curve Enabling 0 2147483647 1 0 Seconds DHFW WinTms ING 2.3.2 AO182 Time Window Frequency-Watt Curve Enabling 0 2147483647 1 0 Seconds DHFW RmpTms ING 2.3.2 AO183 Ramp Time Frequency-Watt Curve Reversion 0 2147483647 1 0 Seconds DHFW RvrtTms ING 2.3.2 AO184 Timeout Period Frequency-Watt Curve Signal 0 2147483647 1 0 n/a DHFW EcpRef 27 ORG 2.6.8 AO185 Meter ID Frequency-Watt Curve - Curve 0 2147483647 1 0 n/a DHFW HzWCrv ASG 2.6.8 AO186 Index Frequency-Watt Curve – High 0 2147483647 1 0 n/a DHFW HysCrv ASG 2.6.8 AO187 Frequency Hysteresis Curve Index Frequency-Watt Curve – Low 0 2147483647 1 0 n/a DLFW HysCrv ASG 2.6.8 AO188 Frequency Hysteresis Curve Index AO189 Frequency-Watt Curve Start Delay 0 2147483647 1 0 Millisec DHFW ActStrDlTmms ING 2.5.3 AO190 Frequency-Watt Curve Stop Delay 0 2147483647 1 0 Millisec DHFW ActStopDlTmms ING 2.5.3 Frequency-Watt Curve Ramp Up 0 2147483647 1 0 Seconds DHFW OpnLoopMax ING 2.3.4 AO191 Time Constant Frequency-Watt Curve Ramp 0 2147483647 1 0 Seconds DHFW OpnLoopMax ING 2.3.4 AO192 Down Time Constant 0 500000 0.1 0 Percent DHFW RpuRte ING 2.3.4 Frequency-Watt Curve Discharge AO193 per Ramp Up Rate Second

27 DHFW.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.Hz

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 0 500000 0.1 0 Percent DHFW RpdRte ING 2.3.4 Frequency-Watt Curve Discharge AO194 per Ramp Down Rate Second 0 500000 0.1 0 Percent DHFW RpuChaRte ING 2.3.4 Frequency-Watt Curve Charge AO195 per Ramp Up Rate Second 0 500000 0.1 0 Percent DHFW RpdChaRte ING 2.3.4 Frequency-Watt Curve Charge AO196 per Ramp Down Rate Second Frequency-Watt Curve Minimum 0 1000 0.1 0 Percent DHFW SocUseMinPct ING 2.6.5 AO197 Usable SOC Frequency-Watt Curve Maximum 0 1000 0.1 0 Percent DHFW SocUseMaxPct ING 2.6.5 AO198 Usable SOC 0 number of 1 0 n/a DVAR ModPrio ING 2.10.4 AO199 Constant VArs Mode Priority modes Constant VArs Enabling Time 0 2147483647 1 0 Seconds DVAR WinTms ING 2.3.2 AO200 Window Constant VArs Enabling Ramp 0 2147483647 1 0 Seconds DVAR RmpTms ING 2.3.2 AO201 Time Constant VArs Reversion Timeout 0 2147483647 1 0 Seconds DVAR RvrtTms ING 2.3.2 AO202 Period Constant VArs Reactive Power -1000 1000 0.1 0 Percent DVAR VArTgtPct ASG 2.7.1 AO203 Target Constant VArs Ramp UpTime 0 2147483647 1 0 Seconds DVAR OpnLoopMax ING 2.3.4 AO204 Constant Constant VArs Ramp Down Time 0 2147483647 1 0 Seconds DVAR OpnLoopMax ING 2.3.4 AO205 Constant 0 number of 1 0 n/a DFPF ModPrio ING 2.10.4 AO206 Fixed Power Factor Mode Priority modes Fixed Power Factor Enabling 0 2147483647 1 0 Seconds DFPF WinTms ING 2.3.2 AO207 Time Window Fixed Power Factor Enabling 0 2147483647 1 0 Seconds DFPF RmpTms ING 2.3.2 AO208 Ramp Time

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class

Fixed Power Factor Reversion 0 2147483647 1 0 Seconds DFPF RvrtTms ING 2.3.2 AO209 Timeout Period Fixed Power Factor Setpoint – 0 100 0.01 0 None DFPF PFGnTgt ASG 2.7.2 AO210 Generation / Discharging Fixed Power Factor Setpoint - 0 100 0.01 0 None DFPF PFLodTgt ASG 2.7.2 AO211 Charging 0 number of 1 0 n/a DVVR ModPrio ING 2.10.4 AO212 Volt-VAR Control Mode Priority modes Volt-VAR Control Enabling Time 0 2147483647 1 0 Seconds DVVR WinTms ING 2.3.2 AO213 Window Volt-VAR Control Enabling Ramp 0 2147483647 1 0 Seconds DVVR RmpTms ING 2.3.2 AO214 Time Volt-VAR Control Reversion 0 2147483647 1 0 Seconds DVVR RvrtTms ING 2.3.2 AO215 Timeout Period 0 2147483647 1 0 n/a DVVR EcpRef 28 ORG 2.7.3 AO216 Volt-VAR Control Signal Meter ID

0 2147483647 1 0 n/a DVVR VVArCrv CSG 2.7.3 AO217 Volt-VAR Curve Index

0 2147483647 1 0 Seconds DVVR OpnLoopMax ING 2.3.4 AO218 Volt-VAr Ramp UpTime Constant

Volt-VAr Ramp Down Time 0 2147483647 1 0 Seconds DVVR OpnLoopMax ING 2.3.4 AO219 Constant Volt-VAr Autonomous Voltage 0 2147483647 1 0 Seconds DVVR VRefTmms ING 2.3.4 AO220 Reference Adjustment Time Constant 0 number of 1 0 n/a DWVR ModPrio ING 2.10.4 AO221 Watt-VAr Mode Priority modes 0 2147483647 1 0 Seconds DWVR WinTms ING 2.3.2 AO222 Watt-VAr Enabling Time Window

28 DVVR.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXN.Vol

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 0 2147483647 1 0 Seconds DWVR RmpTms ING 2.3.2 AO223 Watt-VAr Enabling Ramp Time

Watt-VAr Reversion Timeout 0 2147483647 1 0 Seconds DWVR RvrtTms ING 2.3.2 AO224 Period 0 2147483647 1 0 n/a DWVR EcpRef 29 ORG 2.7.4 AO225 Watt-VAr Signal Meter ID

0 2147483647 1 0 n/a DWVR WVArCrv CSG 2.7.4 AO226 Watt-VAr Curve Index

0 2147483647 1 0 Seconds DWVR OpnLoopMax ING 2.3.4 AO227 Watt-VAr Ramp UpTime Constant

Watt-VAr Ramp Down Time 0 2147483647 1 0 Seconds DWVR OpnLoopMax ING 2.3.4 AO228 Constant Power Factor Correction Mode 0 number of 1 0 n/a DPFC ModPrio ING 2.10.4 AO229 Priority modes Power Factor Correction Enabling 0 2147483647 1 0 Seconds DPFC WinTms ING 2.3.2 AO230 Time Window Power Factor Correction Enabling 0 2147483647 1 0 Seconds DPFC RmpRte ASG 2.3.2 AO231 Ramp Time Power Factor Correction 0 2147483647 1 0 Seconds DPFC RvrtTms ING 2.3.2 AO232 Reversion Timeout Period Power Factor Correction Signal 0 2147483647 1 0 n/a DPFC EcpRef 30 ORG 2.7.5 AO233 Meter ID Power Factor Correction Average -100 100 0.01 0 None DPFC PFTrg ASG 2.7.5 AO234 PF Target Power Factor Correction Lower -100 100 0.01 0 None DPFC PFCorRef.rangeC Int 2.7.5 AO235 PF Limit Power Factor Correction Upper -100 100 0.01 0 None DPFC PFCorRef.rangeC Int 2.7.5 AO236 PF Limit

29 DWVR.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotW 30 DPFC.EcpRef refers to an instance of DECP.ElcMsRef which refers to an instance of MMXU.TotPF

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 0 number of 1 0 None DPRG ModPrio ING 2.10.4 AO237 Pricing Mode Priority modes Pricing Mode Enabling Time 0 2147483647 1 0 Seconds DPRG WinTms ING 2.3.2 AO238 Window Pricing Mode Enabling Ramp 0 2147483647 1 0 Seconds DPRG RmpTms ING 2.3.2 AO239 Time Pricing Mode Reversion Timeout 0 2147483647 1 0 Seconds DPRG RvrtTms ING 2.3.2 AO240 period -2147483648 2147483647 0.01 0 100ths of DPRG PrcRef MV 2.8 Pricing Mode Setpoint. local AO241 Hundredths of local currency per currency Kilowatt-Hr.

Pricing Mode Time Constant 0 2147483647 1 0 Seconds DPRG OpnLoopMax ASG 2.3.4 AO242 Ramp Up Time Pricing Mode Time Constant 0 2147483647 1 0 Seconds DPRG OpnLoopMax ASG 2.3.4 AO243 Ramp Down Time Curve Edit Selector. Writing to 1 2147483647 1 0 n/a DGSM InCrv ORG 2.3.3 this point selects which of the AO244 curves can currently be viewed and changed.

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class

Curve Mode Type. Enumeration: 0 20 1 0 None DGSM ModTyp ENG 2.3.3 <0> Curve disabled (list) <1> Not applicable / Unknown <2> Volt-Var modes <3> Frequency-Watt mode <4> Watt-VAr mode <5> Voltage-Watt modes <6> Remain Connected <7> Temperature mode <8> Pricing signal mode High Voltage ride-through curves <9> HVRT Must Trip <10> HVRT Momentary Cessation AO245 Low Voltage ride-through curves <11> LVRT Must Trip <12> LVRT Momentary Cessation High Frequency ride-through curves <13> HFRT Must Trip <14> HFRT Momentary Cessation Low Frequency ride-through curves <15> LFRT Must Trip <16> LFRT Mandatory Operation 0 100 1 0 n/a FMAR PairArr.NumPts CSG 2.3.3 AO246 Curve Number of Points

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 0 255 1 0 None FMAR IndpUnits ENG 2.3.3 Independent (X-Value) Units for (list) Curve. Enumeration: <0> Curve disabled <1> Not applicable / Unknown <4> Time <29> Voltage <33> Frequency <38> Watts AO247 <23> Celsius Temperature <100> Price in hundredths of local currency <129> Percent Voltage <133> Percent Frequency <138> Percent Watts <233> Frequency Deviation <234+> Other

Dependent (Y-Value) Units for 0 255 1 0 None FMAR DepRef ENG 2.3.3 Curve. Enumeration: (list) <0> Curve disabled <1> Not applicable / unknown <2> VArs as percent of max VArs (VARMax) <3> VArs as percent of max available VArs (VArAval) <4> Vars as percent of max Watts (Wmax) – not used AO248 <5> Watts as percent of max Watts (Wmax) <6> Watts as percent of frozen active power (DeptSnptRef) <7> Power Factor in EEI notation <8> Volts as a percent of the nominal voltage (VRef) <9> Frequency as a percent of the nominal grid frequency (ECPNomHz)

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class <99+> Other

see scaling 0 Varies FMAR PairArr.CrvPts[1].xV CSG 2.3.3 table al AO249 Curve Point 1 X-Value depending on Mode Type see scaling 0 Varies FMAR PairArr.CrvPts[1].yV CSG 2.3.3 table al AO250 Curve Point 1 Y-Value depending on Mode Type see scaling 0 Varies FMAR PairArr.CrvPts[2].xV CSG 2.3.3 table al AO251 Curve Point 2 X-Value depending on Mode Type see scaling 0 Varies FMAR PairArr.CrvPts[2].yV CSG 2.3.3 table al AO252 Curve Point 2 Y-Value depending on Mode Type

AO253 - Curve X-Value, Y-Value pairs for AO446 curve points 3 -99 see scaling 0 Varies FMAR PairArr.CrvPts[100]. CSG 2.3.3 table xVal AO447 Curve Point 100 X-Value depending on Mode Type see scaling 0 Varies FMAR PairArr.CrvPts[100]. CSG 2.3.3 table yVal AO448 Curve Point 100 Y-Value depending on Mode Type

System Meter Active Power – 0 2147483647 1 0 Watts MMXU TotW.rangeC.hLim MV 2.4.3 AO449 High Threshold System Meter Active Power – Low 0 2147483647 1 0 Watts MMXU TotW.rangeC.lLim MV 2.4.3 AO450 Threshold

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class System Meter Reactive Power – 0 2147483647 1 0 VARs MMXU TotVAr.rangeC.hLim MV 2.4.3 AO451 High Threshold System Meter at Reactive Power 0 2147483647 1 0 VARs MMXU TotVAr.rangeC.lLim MV 2.4.3 AO452 – Low Threshold System Meter at Power Factor – -100 100 0.01 0 None MMXU TotPF.rangeC.hLim MV 2.4.3 AO453 High Threshold System Meter at Power Factor – -100 100 0.01 0 None MMXU TotPF.rangeC.lLim MV 2.4.3 AO454 Low Threshold System Meter Phase A Volts – 0 2147483647 0.1 0 Volts MMXU PhV.phsA.rangeC.h WYE 2.4.3 AO455 High Threshold Lim System Meter Phase A Volts – 0 2147483647 0.1 0 Volts MMXU PhV.phsA.rangeC.lLi WYE 2.4.3 AO456 Low Threshold m System Meter Phase B Volts – 0 2147483647 0.1 0 Volts MMXU PhV.phsB.rangeC.h WYE 2.4.3 AO457 High Threshold Lim System Meter Phase B Volts – 0 2147483647 0.1 0 Volts MMXU PhV.phsB.rangeC.lLi WYE 2.4.3 AO458 Low Threshold m System Meter Phase C Volts – 0 2147483647 0.1 0 Volts MMXU PhV.phsC.rangeC.h WYE 2.4.3 AO459 High Threshold Lim System Meter Phase C Volts – 0 2147483647 0.1 0 Volts MMXU PhV.phsC.rangeC.lL WYE 2.4.3 AO460 Low Threshold im

Schedule Analog Outputs 0 2147483647 1 0 n/a FSCC Schd ORG 2.4.3 S Schedule to Edit Selector. (S = 461 for Selects which of the schedules this version can be currently viewed and of the spec) changed.

0 2147483647 1 0 n/a FSCC Schd ORG 2.4.3 S + 1 Selected Schedule Identity

Selected Schedule Priority. 0 2147483647 1 0 n/a FSCH SchdPrio ING 2.4.3 Priority of the schedule relative to S + 2 other running schedules. Lower values have higher priority over higher values.

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class Selected Schedule Type. 0 30 1 0 None FSCH SchdVal.valEq SCR 2.4.3 Enumeration: (list) <1> Low/High Voltage Ride- Through – Hi Must Trip <2> Low/High Voltage Ride- Through – Low Must Trip <3> Low/High Voltage Ride- Through – Hi Momentary <4> Low/High Voltage Ride- Through – Lo Momentary <5> Low/High Frequency Ride- Through – Hi Must Trip <6> Low/High Frequency Ride- Through – Lo Must Trip <7> Low/High Frequency Ride- Through – Hi Momentary <8> Low/High Frequency Ride- Through – Low Momentary <9> Dynamic Reactive Current S + 3 Support - On/Off <10> Dynamic Volt-Watt - On/Off <11> Frequency-Watt - On/Off <12> Active Power Limit - Charging <13> Active Power Limit - Generating <14> Charge/Discharge - Percent of Maximum <15> Coordinated Charge/Discharge - SOC Target <16> Active Power Response #1 - On/Off <17> Active Power Response #2 - On/Off <18> Active Power Response #3 - On/Off <19> AGC – Watts <20> Active Power Smoothing -

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class On/Off <21> Volt-Watt – Curve Index <22> Frequency-Watt Curve – Curve Index <23> Frequency-Watt Curve – High Hysteresis <24> Frequency-Watt Curve – Low Hysteresis <25> Constant VArs - Percent of Maximum <26> Fixed Power Factor - Power Factor <27> Volt-VAr – Curve Index <28> Watt-VAr – Curve Index <29> Power Factor Correction - On/Off <30> Reserved - For pricing mode

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class Selected Schedule Start Date. 0 2147483647 1 0 Days FSCH StrTm TSG 2.4.3 S + 4 Number of days since January 1, 1970, UTC. Selected Schedule Start Time. 0 86400000 1 0 Milli- FSCH StrTm TSG 2.4.3 S + 5 Milliseconds since the start of seconds Schedule Start Date. Selected Schedule Repeat 0 2147483647 1 0 n/a FSCH NxtStrTm TCS 2.4.3 Interval. Interval between actions S + 6 after the initial occurrence. A zero value means the schedule is not repeated. Selected Schedule Repeat 0 8 1 0 None FSCH SchdReuse SPG 2.4.3 Interval Units (list) <0> = No Repeat <1> = Seconds <2> = Minutes <3> = Hours S + 7 <4> = Days <5> = Weeks <6> = Months <7> = Months on Same Day of Week <8> = Months on Same Day of Week from End Selected Schedule Number of 0 100 1 0 n/a FSCH NumEntr ING 2.4.3 S + 8 Points Selected Schedule Point [1] Time 0 2147483647 1 0 Seconds 2.4.3 Offset S+(2(sp-1) Number of seconds from the start + 9) of the schedule when this point becomes active. S+(2(sp-1) -2147483648 2147483647 1 0 varies FSCH SchdEntr INS 2.4.3 Selected Schedule Point[1] Value + 10)

. Selected Schedule Time Offset . and Value points 32- 99. .

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class S+(2(sp-1) Selected Schedule Point [100] 0 2147483647 1 0 Seconds 2.4.3 + 9) Time Offset S+(2(sp-1) Selected Schedule Point[100] -2147483648 2147483647 1 0 varies FSCH SchdEntr INS 2.4.3 + 10) Value Meter Historian Analog Outputs Meter #1 Active Power – High 0 2147483647 1 0 Watts MMXU TotW.rangeC.hLim MV 2.4.3 HM Threshold Meter #1 Active Power – Low 0 2147483647 1 0 Watts MMXU TotW.rangeC.lLim MV 2.4.3 HM + 1 Threshold Meter #1 Reactive Power – High 0 2147483647 1 0 VARs MMXU TotVAr.rangeC.hLim MV 2.4.3 HM + 2 Threshold Meter #1 at Reactive Power – 0 2147483647 1 0 VARs MMXU TotVAr.rangeC.lLim MV 2.4.3 HM + 3 Low Threshold Meter #1 at Power Factor – High -100 100 0.01 0 None MMXU TotPF.rangeC.hLim MV 2.4.3 HM + 4 Threshold Meter #1 at Power Factor – Low -100 100 0.01 0 None MMXU TotPF.rangeC.lLim MV 2.4.3 HM + 5 Threshold Meter #1 Phase A Volts – High 0 2147483647 0.1 0 Volts MMXU PhV.phsA.rangeC.h WYE 2.4.3 HM + 6 Threshold Lim Meter #1 Phase A Volts – Low 0 2147483647 0.1 0 Volts MMXU PhV.phsA.rangeC.lLi WYE 2.4.3 HM + 7 Threshold m Meter #1 Phase B Volts – High 0 2147483647 0.1 0 Volts MMXU PhV.phsB.rangeC.h WYE 2.4.3 HM + 8 Threshold Lim Meter #1 Phase B Volts – Low 0 2147483647 0.1 0 Volts MMXU PhV.phsB.rangeC.lLi WYE 2.4.3 HM + 9 Threshold m Meter #1 Phase C Volts – High 0 2147483647 0.1 0 Volts MMXU PhV.phsC.rangeC.h WYE 2.4.3 HM + 10 Threshold Lim Meter #1 Phase C Volts – Low 0 2147483647 0.1 0 Volts MMXU PhV.phsC.rangeC.lL WYE 2.4.3 HM + 11 Threshold im . . Meter #2. . . . Meter #m-1 points .

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class

HM + Meter #m Active Power – High 0 2147483647 1 0 Watts MMXU TotW.rangeC.hLim MV 2.4.3 mhao(m) Threshold HM + 0 2147483647 1 0 Watts MMXU TotW.rangeC.lLim MV 2.4.3 mhao(m) + Meter #m Active Power – Low Threshold 1 HM + 0 2147483647 1 0 VARs MMXU TotVAr.rangeC.hLim MV 2.4.3 mhao(m) + Meter #m Reactive Power – High Threshold 2 HM + 0 2147483647 1 0 VARs MMXU TotVAr.rangeC.lLim MV 2.4.3 mhao(m) + Meter #m Reactive Power – Low Threshold 3 HM + -100 100 0.01 0 None MMXU TotPF.rangeC.hLim MV 2.4.3 mhao(m) + Meter #m Power Factor – High Threshold 4 HM + -100 100 0.01 0 None MMXU TotPF.rangeC.lLim MV 2.4.3 mhao(m) + Meter #m Power Factor – Low Threshold 5 HM + 0 2147483647 0.1 0 Volts MMXU PhV.phsA.rangeC.h WYE 2.4.3 mhao(m) + Meter #m Phase A Volts – High Lim Threshold 6 HM + 0 2147483647 1 0 Volts MMXU PhV.phsA.rangeC.lLi WYE 2.4.3 mhao(m) + Meter #m Phase A Volts – Low m Threshold 7 HM + 0 2147483647 1 0 Volts MMXU PhV.phsB.rangeC.h WYE 2.4.3 mhao(m) + Meter #m Phase B Volts – High Lim Threshold 8 HM + 0 2147483647 1 0 Volts MMXU PhV.phsB.rangeC.lLi WYE 2.4.3 mhao(m) + Meter #m Phase B Volts – Low m Threshold 9 HM + 0 2147483647 1 0 Volts MMXU PhV.phsC.rangeC.h WYE 2.4.3 mhao(m) + Meter #m Phase C Volts – High Lim Threshold 10 HM + Meter #m Phase C Volts – Low 0 2147483647 1 0 Volts MMXU PhV.phsC.rangeC.lL WYE 2.4.3 mhao(m) + Threshold im

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class 11

Inverter Historian Analog Outputs

Inverter #1 Active Power Output – 0 2147483647 1 0 Watts MMXU TotW.RangeC.hLim MV 2.4.3 HI High Threshold Inverter #1 Active Power Output – 0 2147483647 1 0 Watts MMXU TotW.RangeC.lLim MV 2.4.3 HI + 1 Low Threshold Inverter #1 Reactive Power 0 2147483647 1 0 VARs MMXU TotVAr.rangeC.hLim MV 2.4.3 HI + 2 Output – High Threshold Inverter #1 Reactive Power 0 2147483647 1 0 VARs MMXU TotVAr.rangeC.lLim MV 2.4.3 HI + 3 Output – Low Threshold Inverter #1 Current Output 0 70000 0.001 0 Hz MMXU Hz.rangeC.hLim MV 2.4.3 HI + 4 Frequency – High Threshold Inverter #1 Current Output 0 70000 0.001 0 Hz MMXU Hz.rangeC.lLim MV 2.4.3 HI + 5 Frequency – Low Threshold Inverter #1 DC Inverter Input 0 2147483647 1 0 Watts MMDC Watt.RangeC.hLim MV 2.4.3 HI + 6 Power – High Threshold Inverter #1 DC Inverter Input 0 2147483647 1 0 Watts MMDC Watt.RangeC.lLim MV 2.4.3 HI + 7 Power – Low Threshold Inverter #1 DC Current Available 0 2147483647 1 0.1 Amps MMDC Amp.RangeC.hLim MV 2.4.3 HI + 8 – High Threshold Inverter #1 DC Current Available 0 2147483647 1 0.1 Amps MMDC Amp.RangeC.lLim MV 2.4.3 HI + 9 – Low Threshold Inverter #1 DC Voltage Between 0 2147483647 0.1 0 Volts MMDC Vol.RangeC.hLim MV 2.4.3 HI + 10 DER System and Inverter – High Threshold Inverter #1 DC Voltage Between 0 2147483647 0.1 0 Volts MMDC Vol.RangeC.lLim MV 2.4.3 HI + 11 DER System and Inverter – Low Threshold . Inverter #2 through Inverter #i-1 . points .

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class

Inverter #i Active Power Output – 0 2147483647 1 0 Watts MMXU TotW.RangeC.hLim MV 2.4.3 HI + ihao(i) High Threshold HI + ihao(i) Inverter #i Active Power Output – 0 2147483647 1 0 Watts MMXU TotW.RangeC.lLim MV 2.4.3 + 1 Low Threshold HI + ihao(i) Inverter #i Reactive Power Output 0 2147483647 1 0 VARs MMXU TotVAr.rangeC.hLim MV 2.4.3 + 2 – High Threshold HI + ihao(i) Inverter #i Reactive Power Output 0 2147483647 1 0 VARs MMXU TotVAr.rangeC.lLim MV 2.4.3 + 3 – Low Threshold HI + ihao(i) Inverter #i Current Output 0 70000 0.001 0 Hz MMXU Hz.rangeC.hLim MV 2.4.3 + 4 Frequency – High Threshold HI + ihao(i) Inverter #i Current Output 0 70000 0.001 0 Hz MMXU Hz.rangeC.lLim MV 2.4.3 + 5 Frequency – Low Threshold HI + ihao(i) Inverter #i DC Inverter Input 0 2147483647 1 0 Watts MMDC Watt.RangeC.hLim MV 2.4.3 + 6 Power – High Threshold HI + ihao(i) Inverter #i DC Inverter Input 0 2147483647 1 0 Watts MMDC Watt.RangeC.lLim MV 2.4.3 + 7 Power – Low Threshold HI + ihao(i) Inverter #i DC Input Current 0 2147483647 1 0.1 Amps MMDC Amp.RangeC.hLim MV 2.4.3 + 8 Available – High Threshold HI + ihao(i) Inverter #i DC Input Current 0 2147483647 1 0.1 Amps MMDC Amp.RangeC.lLim MV 2.4.3 + 9 Available – Low Threshold HI + ihao(i) Inverter #i DC Voltage Between 0 2147483647 0.1 0 Volts MMDC Vol.RangeC.hLim MV 2.4.3 DER System and Inverter – High + 10 Threshold HI + ihao(i) Inverter #i DC Voltage Between 0 2147483647 0.1 0 Volts MMDC Vol.RangeC.lLim MV 2.4.3 DER System and Inverter – Low + 11 Threshold Battery Historian Analog Outputs Battery Bank #1 External Voltage 0 2147483647 0.1 0 Volts DBAT ExtVolHiAls MV 2.4.3 HB - High Threshold Battery Bank #1 External Voltage 0 2147483647 0.1 0 Volts DBAT ExtVolLoAls MV 2.4.3 HB + 1 - Low Threshold

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Transmitted Value Scaling IEC 61850 Point Refer Name/Description Units Index Multi- Off- LN To Minimum Maximum Data Object CDC plier Set Class

Battery Bank #1 Internal Voltage – 0 2147483647 0.1 0 Volts DBAT IntnVolHiAls MV 2.4.3 HB + 2 High Threshold Battery Bank #1 Internal Voltage – 0 2147483647 0.1 0 Volts DBAT IntnVolLoAls MV 2.4.3 HB + 3 Low Threshold

. Battery Bank #2 . . . Battery Bank . #b-1 points .

HB + Battery Bank #b External Voltage 0 2147483647 0.1 0 Volts DBAT ExtVolHiAls MV 2.4.3 bhao(b) - High Threshold HB + Battery Bank #b External Voltage 0 2147483647 0.1 0 Volts DBAT ExtVolLoAls MV 2.4.3 bhao(b) + 1 - Low Threshold HB + Battery Bank #b Internal Voltage – 0 2147483647 0.1 0 Volts DBAT IntnVolHiAls MV 2.4.3 bhao(b) + 2 High Threshold HB + Battery Bank #b Internal Voltage – 0 2147483647 0.1 0 Volts DBAT IntnVolLoAls MV 2.4.3 bhao(b) + 3 Low Threshold

Vendor-Specific Analog Outputs

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Table 20 – Scaling for Generic Curve Independent Variables (X-Value) Multipli Independent Variable (X-Value) Units (AO247) Curve Mode Type (AO248) Min Max Units er <0> Curve is not defined <0> Curve is not defined ------<1> Not applicable / Unknown <1> Not applicable / Unknown ------

<6> Remain Connected <9> HVRT Must Trip <10> HVRT Momentary Cessation <11> HVRT Continuous Operation Low Voltage ride-through curves <12> LVRT Must Trip <13> LVRT Momentary Cessation <14> LVRT Continuous Operation <4> Time 0 2147483647 1 ms High Frequency ride-through curves <15> HFRT Must Trip <16> HFRT Mandatory Operation <17> HFRT Continuous Operation Low Frequency ride-through curves <18> LFRT Must Trip <19> LFRT Mandatory Operation <20> LFRT Continuous Operation <29> Voltage <2> Volt-VAr modes 0 2147483647 1 Volts <33> Frequency <3> Frequency-Watt mode 0 7000 0.01 Hz <38> Watts <4> Watt-VAr mode 0 2147483647 1 Watts <23> Celsius Temperature <7> Temperature mode -5000 5000 0.1 Degrees 100ths of <100> Price in hundredths of local currency <8> Price Signal -2147483648 2147483647 0.01 local currency <2> Volt-VAr modes <129> Percent Voltage (of VRef - AO0) 0 1000 0.1 % <5> Voltage-Watt modes <133> Percent Frequency (of ECPNomHz - AO2) <3> Frequency-Watt mode 0 1000 0.1 % <138> Percent Watts (of WMax - AI32) <4> Watt-Power Factor mode 0 1000 0.1 % <233> Frequency Deviation <3> Frequency-Watt mode 0 7000 0.01 Hz

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Table 21 – Scaling for Generic Curve Dependent Variables (Y-Value) Dependent Variable (Y-Value) Units (AO248) Curve Mode Type (AO248) Min Max Multiplier Units <0> Curve is not defined <0> Curve is not defined ------<1> Not applicable / unknown <1> Not applicable / Unknown ------<2> VArs as percent of max VArs (VArMax - AI34, AI35) <2> Volt-VAr modes -1000 1000 0.1 % <3> VArs as percent of max available VArs (AI45, AI46) <2> Volt-VAr modes -1000 1000 0.1 % <4> Vars as percent of max Watts (WMax - AI32,AI33) <2> Volt-VAr modes -1000 1000 0.1 % <3> Frequency-Watt mode <5> Watts as percent of max Watts (WMax - AI32,AI33) 0 1000 0.1 % <5> Voltage-Watt modes <6> Watts as percent of frozen active power (DeptSnptRef - AI) <3> Frequency-Watt mode 0 1000 0.1 % <7> Power Factor <4> Watt-Power Factor mode -100 100 0.01 None High-Voltage ride-through curves <6> Remain connected <9> HVRT Must Trip <10> HVRT Momentary Cessation <11> HVRT Continuous Operation <8> Volts as a percent of nominal Voltage (VRef, AO + AO) 0 1000 0.1 % Low Voltage ride-through curves <12> LVRT Must Trip <13> LVRT Momentary Cessation <14> LVRT Continuous Operation

High Frequency ride-through curves <15> HFRT Must Trip <16> HFRT Mandatory Operation <17> HFRT Continuous Operation <9> Frequency as a percent of the nominal grid frequency (ECPNomHz) 0 1000 0.1 % Low Frequency ride-through curves <18> LFRT Must Trip <19> LFRT Mandatory Operation <20> LFRT Continuous Operation <99+> Other

NOTE: This profile does not require that an outstation support any particular Y-Value Units (e.g. Watts) for Mode Type of <7> Temperature or <8> Price Signal. It is possible that an outstation may permit the master to choose between different Y-Value units by selecting a different value in AO248.

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Table 22 – Analog Output Protocol Options 3.6 ANALOG OUTPUT STATUS and ANALOG OUTPUT CONTROL BLOCK Analog Output Status Group Number: 40 Capabilities Analog Output Control Block Group Number: 41 Analogue Output Event Group Number: 42 Analogue Output Command Event Group Number: 43

3.6.1 Static Analog Output Status Variation reported when variation 0 requested or  Variation 1 – 32-bit with flag in response to Class polls:  Variation 2 – 16-bit with flag  Variation 3 – single-precision floating point with flag  Variation 4 – double-precision floating point with flag  Based on point Index (add column to table in part 5)

3.6.2 Analog Output Status Included in Class 0 response:  Always  Never (must poll for them separately)  Only if the point is assigned to a class  Based on point Index

3.6.3 Reports Output Command Event Objects:  Never  Only upon a successful Control  Upon all control attempts

3.6.4 Event Variation reported when variation 0 requested or in response to Class  Variation 1 – 32-bit without time polls:  Variation 2 – 16-bit without time

 Variation 3 – 32-bit with time Note: The support for analog output events can be determined remotely using protocol object Group 0 Variation 219.  Variation 4 – 16-bit with time  Variation 5 – single-precision floating point w/o time  Variation 6 – double-precision floating point w/o time  Variation 7 – single-precision floating point with time  Variation 8 – double-precision floating point with time  Based on point Index (add column to table in part 5)

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3.6 ANALOG OUTPUT STATUS and ANALOG OUTPUT CONTROL BLOCK Analog Output Status Group Number: 40 Capabilities Analog Output Control Block Group Number: 41 Analogue Output Event Group Number: 42 Analogue Output Command Event Group Number: 43

3.6.5 Command Event Variation reported when variation 0 requested:  Variation 1 – 32-bit without time  Variation 2 – 16-bit without time  Variation 3 – 32-bit with time  Variation 4 – 16-bit with time  Variation 5 – single-precision floating point w/o time  Variation 6 – double-precision floating point w/o time  Variation 7 – single-precision floating point with time  Variation 8 – double-precision floating point with time  Based on point Index (add column to table in part 5)

3.6.6 Event reporting mode:  Only most recent When responding with event data and more than one event has occurred for a data  All events point, an Outstation may include all events or only the most recent event.

3.6.7 Command Event reporting mode:  Only most recent When responding with event data and more than one event has occurred for a data  All events point, an Outstation may include all events or only the most recent event.

3.6.8 Maximum Time between Select and Operate:  Not Applicable  Fixed at _____ seconds  Configurable, range ___1___ to ___30___ seconds  Configurable, selectable from___,___,___seconds  Configurable, other, describe______ Variable, explain ______ Based on point Index (add column to table in part 5)

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3.6.9 Analog Outputs Event Buffer Organization:  Fixed at ______When event buffers are allocated per object group (see part 1.7.6), indicate the  Configurable, range ______to ______number of events that can be buffered for Analog Outputs. If event buffers are not allocated per object group then set “Fixed at 0”.  Configurable, selectable from ____,____,____  Configurable, other, describe______

3.6.10 Analog Output Commands Event Buffer Organization:  Fixed at ______When event buffers are allocated per object group (see part 1.7.6), indicate the  Configurable, range ______to ______number of events that can be buffered for Analog Output Commands. If event buffers are not allocated per object group then set “Fixed at 0”.  Configurable, selectable from ____,____,____  Configurable, other, describe______

2.2.10 Device Attribute Objects (optional) Compliance with this section is optional. As discussed in 1.2, it is an industry requirement that this profile not exceed DNP3-L2. However, some “nameplate” data required by IEEE Std 1547 is not available via DNP3-L2 data objects. For complete compliance with IEEE Std 1547 it is recommended that the outstation implement Device Attribute objects as described in this section. Note, however, that most of the IEEE Std 1547 nameplate data is also available by reading Analog Inputs, which are compatible with DNP3-L2. Table 23 contains all the standard Device Attribute objects, found by reading point number 0 of object group 0. If implementing Device Attribute Objects, the outstation shall provide all of these objects to the master when the master requests them, as indicated in section 2.12. Note that further information regarding the time synchronization source and accuracy shall also be provided by the outstation in section 10.1 of the Device Profile document. Table 24 contains Device Attribute objects that are specific to this DNP3 PV/Storage Profile, found by reading point number 2 of object group 0. If the master and outstation agree to implement Device Attribute objects, they shall implement these points. Point number 1 of object group 0 is left for any vendor-specific device attributes the outstation may report. The attributes in Table 24 are nameplate ratings. They are not writeable. The structure of these Device Attribute objects is shown below the table. When the master reads the “Identifier of support for user-specific attributes” at Group 0 Variation 211, point index 0, the outstation shall identify the namespace of the Device Attribute objects in Table 24 as follows: • Attribute data type code: 1 (VSTR)

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• Length: 19 • User attribute set: “PVStorage.Basic, 2”

If the device supports additional user attribute sets, their namespace identifiers shall be included in the User Attribute Set string along with “PVStorage.Basic, 2” as described in the DNP3 specification. Table 23 – Standard Device Attribute Objects (Point Number 0) IEC 61850 Group 0 Name / Description Variation LN LN Class Data Object CDC Inst

211 Device Attributes – Identifier of support for user-specific attributes 212 Device Attributes – Number of master-defined data set prototypes 213 Device Attributes – Number of outstation-defined data set prototypes 214 Device Attributes – Number of master-defined data sets 215 Device Attributes – Number of outstation-defined data sets 216 Device Attributes – Max number of binary outputs per request 217 Device Attributes – Local timing accuracy LTMS 1 TmAcc INS 218 Device Attributes – Duration of timing accuraccy LTMS 1 TmAcc INS 219 Device Attributes – Support for analog output events 220 Device Attributes – Max analog output index 221 Device Attributes – Number of analog outputs 222 Device Attributes – Support for binary output events 223 Device Attributes – Max binary output index 224 Device Attributes – Number of binary outputs 225 Device Attributes – Support for frozen counter events 226 Device Attributes – Support for frozen counters 227 Device Attributes – Support for counter events 228 Device Attributes – Max counter index

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IEC 61850 Group 0 Name / Description Variation LN LN Class Data Object CDC Inst

229 Device Attributes – Number of counter points 230 Device Attributes – Support for frozen analog inputs 231 Device Attributes – Support for analog input events 232 Device Attributes – Maximum analog input index 233 Device Attributes – Number of analog input points 234 Device Attributes – Support for double-bit binary input events 235 Device Attributes – Maximum double-bit binary input index 236 Device Attributes – Number of double-bit binary input points 237 Device Attributes – Support for binary input events 238 Device Attributes – Max binary input index 239 Device Attributes – Number of binary input points 240 Device Attributes – Max transmit fragment size 241 Device Attributes – Max receive fragment size 242 Device Attributes – Device manufacturer’s software version 243 Device Attributes – Device manufacturer’s hardware version 244 Not available – Reserved for future assignment 245 Device Attributes – User-assigned location name 246 Device Attributes – User-assigned ID code/number 247 Device Attributes – User-assigned device name 248 Device Attributes – Device serial number LPHD 1 PhyNam DPL 249 Device Attributes – DNP subset and conformance 250 Device Attributes – Device manufacturer’s product name and model LPHD 1 PhyNam DPL 251 Not available – Reserved for future assignment 252 Device Attributes – Device manufacturer’s name LPHD 1 PhyNam DPL 253 Not available – Reserved for future assignment

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IEC 61850 Group 0 Name / Description Variation LN LN Class Data Object CDC Inst

254 Device Attributes – Non-specific all attributes request 255 Device Attributes – List of attribute variations

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Table 24 – PV/Storage Device Attribute Objects (Point Number 2) IEC 61850 Group 0 Name / Description Variation LN LN Class Data Object CDC Inst

1 - 248 Reserved 249 Nameplate rating – Amps DGEN AMaxRtg ASG 250 Nameplate rating – Volts DGEN VMaxRtg ASG 251 Nameplate rating – Watts DGEN WMaxRtg ASG 252 Nameplate rating - VA DGEN VAMaxRtg ASG 253 Nameplate rating – VAR DGEN IvarMaxRtg ASG 254 Device Attributes – Non-specific all attributes request 255 Device Attributes – List of attribute variations

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The following structure describes the nameplate rating attribute objects for Group 0 (point index 2) variations 250, 251, 252 and 253. Pictorial

octet transmission order  7 6 5 4 3 2 1 0  bit position Attribute data type code Length

Nameplate rating

Formal structure UINT8: Attribute data type code. Specifies the attribute data type code, UINT. (Refer to section 1 of the DNP3 Data Object Library.) UINT8: Length. Specifies the number of octets in the attribute. This octet is always 4 for these attributes. UINT32: The nameplate rating: Watts, VA or VAR The rated Watts, VA or VARs for this device

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2.3 Overview of DER Modes and Functions This section and those that follow describe specifically how to use DNP3 to implement the modes and functions of a DER that are identified in IEC 61850-7-420 and the EPRI document Common Functions for Smart Inverters. Each section lists the steps described in that document and identifies which DNP3 function codes, data types and points shall be used to implement them. For the purposes of this specification, a function is a capability that is typically performed due to human intervention, and does not repeat unless it is requested again. A mode is automatic behavior which is pre- configured, enabled, and then operates either periodically or continuously. In the tables that follow, the DNP3 data types are abbreviated: BI – binary input; BO – binary output; C – counter, AI – analog input; and AO – analog output.

2.3.1 Support for Modes and Functions – NEW Outstations are not required to support all modes or functions. They shall implement modes and functions according to the following rules: 1. If a mode or function is supported by (i.e. implemented in) the outstation, it shall set to the “1” state the appropriate “supports” binary input so the master can easily determine which modes are available for use. For instance, if the binary input “Supports Coordinated Charge/Discharge Mode” (BI38) is set to “1” (Supported), the outstation is capable of performing that mode. 2. The outstation shall not report the “supports” binary inputs in any event class, but only in Class 0 responses since these points shall never change over the course of the DNP3 association. 3. A mode or function that is supported by an outstation may be placed in either enabled or disabled state by the master through the use of a binary output. For example, if the master sets the binary output “Enable Coordinated Charge/Discharge Mode” (BO19) to the “1” (Enabled) state, the outstation will begin performing the mode, subject to the enabling timing parameters described in 2.3.2. 4. If a mode or function is supported by an outstation, it shall implement all the points associated with that mode or function.

NOTE: The process step tables that follow have an “Optionality” column. If this column contains the word “Optional” this means that the master or outstation may not need to perform the step every time it executes the function. It does not mean that the master or outstation is not required to implement the necessary DNP3 features to support the step. To ensure interoperability, it is recommended that all outstations and masters conforming to this profile be capable of performing all the steps described for a particular function, given that it implements that function.

5. If a mode or function is disabled, the input points (BI or AI) for that mode shall have the ONLINE flag set to FALSE to indicate that the data is invalid. If a mode or function is not supported at all, the outstation may remove the associated points from the reported point list, or may leave them in with the ONLINE flag set to FALSE. Point indices of the remaining points shall not change even if some of the points are removed from the points list. The binary inputs indicating which modes are supported by the outstation shall not be removed from the reported points list.

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NOTE: The method recommended by the DNP Users Group to retrieve data is to gather all data at the start of communications (an integrity poll) and read only the changes thereafter (an event poll). Doing so will reduce required bandwidth.

2.3.2 Mode Enabling Timing Parameters Most of the control-oriented modes and functions described herein each include several parameters that affect the timing of the behavior when enabling the mode or function: • An Enabling Time window within which to randomly start the new behavior after the master sends the command to do so. If the Enabling Time Window is zero, the mode or function executes immediately. • An Enabling Ramp Time for the system to gradually move from its current settings to the new settings (if applicable), beginning after the Enabling Time Window. • A Reversion Timeout Period, measured from the end of the Enabling Time Window, after which the mode or function will be disabled. It is assumed that if this parameter is used and the mode is intended to continue, the master will re-enable it before the timeout occurs. When the outstation restarts, the outstation shall set these parameters to default values preconfigured at the outstation. In addition, the values specified in Table 25 have special meanings. Table 25 – Values for Timing Parameters Parameter Meaning of Zero Meaning of 0xFFFF Enabling Time Window Execute the command immediately Use default value Enabling Ramp Time Change to the new setting immediately Use default value Reversion Timeout Period Infinity; never time out Use default value

2.3.3 Multiplexed Generic Curves and Schedules Many of the DER operating modes require the use of a curve, i.e. a set of “X-values” and “Y-values” expressing a relationship between a measured quantity and a desired output. To accommodate these functions without adding an excessive number of DNP3 data points, this profile uses the concept of a multiplexed curve as illustrated in Figure 6. The curves are “generic” in the sense that the same points may be used for curves having different units on the X and Y axes.

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Communications with Master Outstation

Curve #n

Curve #3 Curve Edit Selector Curve #2 Curve Curve #1 • Identity • Curve Mode Type • Num Points • X-Values, Y-Values • X and Y Value Units • Timing Parameters

Figure 6 – Generic Curve Concept

The value of the Curve Edit Selector (AO244) point determines which curve is “visible” to the master at any time. The number in this point is the “index” of the selected curve. A curve may be in one of three states: 1. The curve is being referenced by a DER mode. The Curve Index point for one of the DER modes has the value of the selected curve index and the binary input point named “Selected Curve is Referenced by a Mode” ( BI107) is therefore set to TRUE, 1 by the outstation. 2. The curve is reserved to be referenced by a mode. The Curve Number of Points (AI330) is non- zero but there is no mode with a Curve Index Point having this curve index yet and therefore the binary input point named “Selected Curve is Referenced by a Mode” (BI107) is FALSE, 0. 3. The curve is not in use, i.e. empty. The Curve Number of Points (AI330) is zero. To create a new curve, the master performs the following steps: 1. Changes the Curve Edit Selector to an index number that is “not in use” as just described. The master may be managing which curves are in use on the outstation using the master’s own internal records, or it may search for a curve with the Curve Number of Points (AI330) set to zero and “Selected Curve is Referenced by a Mode” (BI107) set to zero (FALSE). If the master attempts to select a curve that does not exist on the outstation, the outstation shall respond to the request with a PARAMETER ERROR internal indication. 2. Modifies points that define the type (Curve Mode Type, AO245) and units (Independent (X- Value) Units for Curve, AO247, and Dependent (Y-Value) Units for Curve, AO248) for each curve. For instance, instead of a Volt/VAR curve, the curve may be a Frequency-Watt curve, or a Watt-Power Factor curve. 3. Modifies DNP3 data points that define the number of curve points (AO246) and X and Y-Values of each curve (AO249 through AO447). The active points in the curve are defined in a contiguous block starting at the lowest index of the DNP3 point array. A contiguous block of higher-numbered DNP3 points will be unused depending on the number of curve points specified. 4. Modifies points that affect the timing and filtering of the outstation’s response to the curve, as described in the next section.

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5. Selects the curve in the analog output settings for the appropriate mode, e.g. Volt-VAR Curve Index (AO217). This shall cause the outstation to set the the binary input “Selected Curve is Referenced by a Mode” (BI107) to TRUE, 1. 6. Enables the mode, e.g. Enable Volt-VAR Control Mode (BO29). In addition to the generic Curve points, the profile also includes points for a Generic Schedule. There is a “Schedule to Edit Selector” analog output point (S), and an analog input (S+10) used to indicate whether the schedule is “Inactive”, “Ready to Run” or “Running”. Scheduling is discussed in 2.9. NOTE: Once a curve is referenced by a mode and the mode is enabled, the points of the curve are considered “locked”. In other words, if the master attempts to change the X-value or Y-value points of a curve while it is being referenced by an enabled mode, the outstation shall reject the operation setting the ALREADY EXECUTING Internal Indication in the response. To make a change to a curve, the master may disable the mode, edit the curve and re-enable the mode; or alternately, locate an unused curve, edit it, and change the Curve Index of the mode to the index of the new curve, as previously discussed. The master is not required to disable the mode to change the Curve Index of the mode; the outstation shall start using the new curve as soon as the master writes the new Curve Index to the outstation. This NOTE does not apply to Generic Schedules; schedules may be edited while in use by the outstation. This is a general overview of the process. The specific steps and values required to implement each function are defined in the sections that follow. Both the Generic Curve and Generic Schedule definitions permit the master to define up to 100 points for any given curve index or schedule. A value of zero (0) in the Curve Index setting for a DER mode, such as Volt-VAR Curve Index (AO217) shall mean that no curve is selected for that mode.

2.3.4 Limiting Response: Ramp Rates, Ramp Times and Time Constants - NEW The modes and functions described in the following sections may use the parameters described in Table 26 to limit the response of the output from the function. This processing may be applied to prevent damage to the equipment or to reduce undesirable fast variations in the output of the DER. Table 26 describes these parameters in the order in which they shall be applied by the outstation.

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Table 26 – Response Limiting Parameters Priority Category Description Examples The outstation attempts to achieve the output required by • Charge/Discharge Active the operating mode or function based on the inputs it is Power Target (AO93) monitoring, e.g. a setpoint, or a point on a curve, gradient or schedule. • Constant VArs Active Power Target (AO203)

If the Target Value is not a simple setpoint (as for • Curve Point 1 Y-Value Charge/Discharge Active Power), then the outstation shall (AO249) Target report the attempted target value in an analog input 1st Value specific to each mode. For example, Volt-VAr Attempted Output (AI301) shall report the point on the presently- executing Volt-VAr curve the outstation is trying to achieve when Volt-VAr mode is enabled. In some modes such as Volt-Watt or Frequency-Watt in which the curve represents a boundary rather than a requirement, this “attempted” analog input shall represent the maximum or minimum output the outstation will attempt based on its capabilities at the time. The outstation lets the output follow a “natural” rise or fall • Charge/Discharge Time from its present value to the target value, as specified by a Constant Ramp Up Time time constant. All the time constant analog output points in (AO94) this profile shall be interpreted in one of two ways, depending on the value of the Time Constant Mode binary • Constant VArs Time output (BO9): Constant Ramp Down Time (AO205) • An open loop response time. The value of the analog output is the maximum interval in which the Time output will settle to the percentage of the target value 2nd Constants specified in the Open Loop Response Time Percentage (AO3). For example, the IEEE 1547 standard requires an Open Loop Response time representing 90% of the target value. • A time constant for a lowpass filter, as discussed below. The value of the analog output is the maximum 3τ (3 x tau) time period in which the output will settle to 95% of the target. Some European Grid Codes use this method of specification. • Active Power Smoothing Mode- If the “natural” rise or fall of the output would exceed a Discharge Ramp Down Rate Specific specific ramp rate defined for the mode, curve, or 3rd (AO165) Ramp schedule, the outstation shall limit the output to that Rates specific ramp rate. • Volt-Watt Charging Ramp Up Rate (AO179) In addition to any other restrictions, the outstation shall not • Maximum Generation Ramp Maximum Up Rate (AI177) th exceed the maximum ramp rates listed in the SCADA and 4 Ramp Configuration points. Rates • Maximum Charging Ramp Down Rate (AI180)

Some of the DER operating modes use both time constants and mode-specific ramp rates; some use one or the other, and some use neither. Table 27 describes which parameters are used by which modes.

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Table 27 – Use of Time Constants and Ramp Rates Has Time Has Mode Output Constant Ramp Notes Pts Rate Pts Voltage Ride-Through Must-Trip No No Neither applies Frequency Ride-Through Must-Trip No No Neither applies Dynamic Reactive Current Current No No Neither applies Dynamic Volt-Watt Active No No Neither applies Frequency-Watt Active Yes Yes Uses time constants, then ramp rates Active Power Limit Active No No Uses only the maximum ramp rates Charge/Discharge Storage Active Yes Yes Uses one or the other based on BO38 Coordinated Charge/Discharge Active No No Uses only the maximum ramp rates Active Power Response Active No Yes Uses only ramp rates Automatic Generation Control Active Yes Yes Use one or the other based on BO39 Active Power Smoothing Active No Yes Uses only ramp rates Uses either just time constant (per IEEE Volt-Watt Active Yes Yes 1547) or both time constants and ramp rates based on BO40. Frequency-Watt Curve Active Yes Yes Uses time constants, then ramp rates Constant VArs Reactive Yes No Uses only time constants Fixed Power Factor Reactive No No Neither applies Volt-VAr Reactive Yes No Uses only time constants Watt-VAr Reactive Yes No Uses only time constants Power Factor Correction Reactive No No Neither applies Price Unknown No No Neither applies

The low-pass filter described in the “Time Constants” row of Table 26 is a first-order filter with a frequency response magnitude given by: Output 1 = Input 1+ ( )2 And in the time domain: Output = Input * ( 1 - e t/τ) Where ω = 2π*frequency and τ = the time constant of the filter. Such a filter results in output as shown in Figure 7 in response to a step change in the input, which in this case would be the target value of the mode or function.

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95% settled

Input in 3 τ Watt Limit Watt Output

Time

Figure 7 – Example Time Domain Response from First-order Low-Pass Filter

2.3.5 Use of Broadcasting The sections which follow specify the interactions between master and outstation assuming that the master is performing the functions on a single outstation. However, it is also envisioned that the master may wish to perform the same functions on many inverters at once. To do so, in the “steps” table for each of the operating modes, the following rules apply: • The master shall send all messages to the Broadcast Address 0xFFFF. • If operating over an IP network, UDP shall be used and it may be appropriate to use IP broadcast addresses. • The master shall substitute “Direct Operate – No Acknowledgement” for any step with “Direct Operate / Response” or “Select/Response, Operate/Response” in the “Function Codes” column to prevent responses from multiple outstations. Note that this lessens the potential reliability of the operation unless follow-up queries are made on a device-by-device basis to verify receipt. • The master shall omit any step with “Read / Response” in the Function Codes column to avoid flooding the communications network with responses from many devices at once. The outstation shall permit a user to configure the ability to accept broadcast messages. If the outstation is configured to not accept broadcast messages, it shall return the INVALID PARAMETER internal indication when it receives a broadcast request and shall not perform the function.

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2.4 Basic DER Functions

2.4.1 Monitoring The steps in Table 28 describe how to monitor the data reported by the DER, as described in IEC 61850- 7-420 and IEC 61850-90-7. Table 28 – Steps to read and report status using the DNP3 DER Profile Function Step Description Optionality Data Type Point Number Codes Class 0, Class 1, Read / All 1. Read all values except setpoints Required Class 2, AND Class Response 3 (qualifier 0x06) Read all values changed (e.g. Read / Class 1, Class 2, All 2. exceeded a deadband) since the Required Response AND Class 3 last report (qualifier 0x06) Read / Analog Output All 3. Read the values of all the setpoints Required Response Status (qualifier 0x06) Read all the points of a particular Read / All (variation 0) 4. Optional See section 2.2 type Response (qualifier 0x06) Report the value of a particular Unsolicited See section 2.2 5. item spontaneously upon change Optional See section 2.2 Response (qualifier 0x28) or exceeding a deadband See section 2.2 and Assign a particular item to a “data Assign See section 2.2 6. Optional one of Class 1, 2 or set” (not DNP3-L2) Class (qualifier 0x28) 3 Remove a particular item from a Assign See section 2.2 and See section 2.2 7. Optional “data set” (not DNP3-L2) Class Class 0 (qualifier 0x28) Read all changes in a current “data Read / All 8. Optional Class 1, 2 OR 3 set” (not DNP3-L2) Response (qualifier 0x06) Device Attribute Read / Objects (not DNP3- See section 9. Read nameplate information Optional Response L2) OR 2.2.10. Analog Inputs

The monitored values are listed in the “points lists” in section 2.2. Because many of them are Analog Output setpoints which do not change very often, and because most of the analog output values are mirrored as analog inputs, the Analog Output Status objects shall not be included in a DNP3 Class 0 poll, as noted in Table 22. To retrieve them shall require a separate poll, as shown in step 3 of Table 28. Note that the term “data set” used by IEC 61850-7-420 for monitoring and status reporting does not refer to DNP3 data set objects in this case. In DNP3, the assignment of data into groups for reporting may be performed either through pre-configuration, or remotely by the ASSIGN CLASS function code, as shown in Table 28. ASSIGN CLASS is not a DNP3-L2 capability, so it is not a requirement of the profile and is shown here only as an example of what may be implemented by agreement between the master and outstation. Similarly, reading nameplate information would ideally be performed by DNP3 by reading Device Attribute Objects. However, these objects are not mandatory in DNP3-L2, so this profile specifies most of the nameplate information as Analog Inputs. A few nameplate items such as Vendor, Model Number and Serial Number are only available as Device Attribute objects. If those items are required remotely, it is recommended the master and outstation make an agreement to implement Device Attributes as described in section 2.2.10.

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2.4.2 Use of Signal Meters Many of the functions in this profile operate autonomously using data provided by a meter. For example, the Frequency-Watt operating mode described in 2.5.3 adjusts the active power output of the DER based on frequency values read from a meter. This meter may be the System Meter located at the connection point of the DER, but it could also be at several other locations as listed in Table 1 and shown in Figure 1 of 2.1.1. In this specification, meters which provide signal data which is used by an autonomous function are referred to as “signal meters.” Each meter that is will be used by one of the DER operating modes is assigned a positive integer, known as a “Signal Meter ID”. The value 0 is used for the Signal Meter ID of the System Meter. If the data from the meter is included in the Historian points, then Meter #1 is the first block of meter points in the Historian points, Meter #2 is the second, etc. Meters not represented in the Historian points are represented by unique positive integers chosen by the outstation that do not overlap with any meters represented in the Historian points.

2.4.3 Alarm Grouping and Reporting - NEW Many of the Binary Input points represent alarms, i.e. a value that if it is in the “1” state, represents an error condition that requires the immediate attention of an operator or engineer. Because there are a large number of possible alarms, this profile specifies the ability for the outstation to “group” alarms by priority. This represents enhanced functionality within the outstation beyond a “passthrough” of data as discussed in IEEE Std 1815.1. The outstation shall implement alarm grouping according to the following rules: 1. Which alarm is placed in which group is considered to be an issue local to the outstation 2. The groups may be pre-configured or fixed. 3. There are three possible priority levels, with “1” being the most important. They may be abbreviated P1, P2 and P3. 4. If the outstation raises (sets to “1”) any alarm with a particular priority level, it shall also raise the corresponding group alarm binary input. 5. When all alarms in a priority level have been cleared/lowered (set to “0”), the outstation shall also clear/lower the group alarm point(s). 6. There are group alarm points at the “system” level and also at the “DER Unit” level. An alarm from the DER Unit shall raise both the DER Unit and System group alarm points.

NOTE: Alarm priority levels are distinct from DNP3 implementation levels (e.g. this entire profile is considered DNP3-L2 – see 1.2) and also from DNP3 event classes (all alarm indications are recommended to be Class 1 – see 2.2.3).

This profile inherits from the IEC 61850 data models the concept that any analog value measured by the outstation shall have alarm “ranges” defined. The outstation shall implement them as follows: 1. Outstations shall permit masters to set the thresholds for these alarms via analog outputs. 2. Outstations shall raise an alarm (in DNP3 terms, a binary input is changed to the “1” state) if the measured value crosses the preset thresholds for that value. 3. If a measured value returns to normal operating range, the outstation shall clear/lower the alarm (return it to the “0” state).

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4. Outstations are required to implement only “high” and “low” ranges as specified in this profile, although IEC 61850 also defines “high high” and “low low” and other alarm ranges. 5. Outstations shall support these alarms and their threshold settings for each value the outstation measures. 6. The default value for the thresholds may be fixed or pre-configured. There is also a systems communications group alarm. There are several communications alarms in the binary inputs points list. If there are any communications problems within the DER, the outstation shall raise the systems communications alarm (BI0).

2.4.4 Connect and Disconnect Functions The steps in Table 29 describe how to cause the DER to physically connect or disconnect from the grid. This function refers to the operation of the DER Connect/ Disconnect” switch identified in 2.1.1. It disconnects the DER from both the utility and local customer loads and leaves any local loads connected to the grid. This function is not the same as an activation of the “Utility Switch” at the Point of Common Coupling, which would leave the DER connected to local loads. The outstation shall start the time window and reversion timeout at the moment the master successfully delivers the switch control command. Since the switch position is not an analog value, there is no ramp time parameter associated with this function. Table 29 – Steps to perform a Connect/Disconnect DER Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set time window Optional Direct Operate / Response AO AO16 AI60 2. Set reversion timeout Optional Direct Operate / Response AO AO17 AI61 Read / Response or 3. Retrieve status of switch Optional BI BI23 n/a Unsolicited Response

Issue switch control Select / Response, 4. command and receive Required BO BO5 BI23 response Operate / Response Read / Response or n/a 5. Detect if switch is moving Optional BI BI24 Unsolicited Response

This profile only specifies the ability to connect or disconnect the DER as a whole. It defines binary input points that indicate other levels of connectivity, e.g. Inverter #1 DC Disconnect Warning (. However, these conditions are not under control of the master.

2.4.5 Cease to Energize and Return to Service Functions – NEW IEEE Std 1547 defines “cease to energize” as “cessation of active power output at the PCC.” Table 30 describes how to put the DER into this state and return it to normal service.

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Table 30 – Steps to cause the DER to Cease to Energize and Return to Service Data Point Read-back Step Description Optionality Function Codes Type Number Point Set Cease to Energize 1. Optional Direct Operate / Response AO AO13 AI57 Time Window Set Cease to Energize 2. Optional Direct Operate / Response AO AO14 AI58 Ramp DownTime Set Cease to Energize 3. Optional Direct Operate / Response AO AO15 AI59 Timeout Period Cause DER to Cease to Select / Response, 4. Required BO BO2 BI14 Energize Operate / Response Give DER Permission to Required Select / Response, 5. BO BO4 BI17 Stop (See Note) Operate / Response Read / Response or 6. Confirm DER is Stopping Optional BI BI13 n/a Unsolicited Response Confirm DER has Ceased Read / Response or 7. Optional BI BI15 n/a to Energize Unsolicited Response 8. Set High Voltage Limit Optional Direct Operate / Response AO AO6 AI50 9. Set Low Voltage Limit Optional Direct Operate / Response AO AO7 AI51 10. Set High Frequency Limit Optional Direct Operate / Response AO AO8 AI52 11. Set Low Frequency Limit Optional Direct Operate / Response AO AO9 AI53 12. Set Delay Time Optional Direct Operate / Response AO AO10 AI54 Set Return to Service 13. Optional Direct Operate / Response AO AO11 AI55 Time Window Set Return to Service 14. Optional Direct Operate / Response AO AO12 AI56 Ramp Up Time Cause DER to Return to Select / Response, 15. Required BO BO1 BI12 Service Operate / Response Give DER Permission to Required Select / Response, 16. BO BO3 BI16 Start (See Note) Operate / Response Read / Response or 17. Confirm DER is Started Optional BI BI14 n/a Unsolicited Response

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NOTE: The master may send the commands to give Permission to Start (BO3) or Stop (BO4) at any time. The DER will check the state of the appropriate permission the next time it starts or stops. If permission is not given, it will not advance to the next state until the permission point is changed. This rule also applies if the DER attempts to start or stop on its own.

2.4.6 Operational States IEC 61850-7-420 specifies multiple DER operational states that are represented by a single enumerated value. An early draft of the state transition diagram is illustrated in Figure 8. This diagram should not be considered authoritative; it is shown here to aid in understanding the growing consensus on how DERs should operate. Table 31 illustrates how the IEC 61850-7-420 states may be represented by binary inputs in this profile. A “Y” in a cell means that binary input is in the “1” or “on” state.

Table 31 – Operational States and Binary Inputs

# IEC 61850 State Name

al State al

onnectedGenerating and

System Is In LocSystemIn Is LockoutSystemState In Is SystemUp Starting Is SystemStopping Is Service) SystemReturn Started to is Energize) System to (Cease Stopped is Status System to Start Permission Status System to Stop Permission is DER Idle Connected and isDER is DER Charging Connected and is to DER but Off Start Available to is Start DER and Off Not Available

BI10 BI11 BI12 BI13 BI14 BI15 BI16 BI17 BI18 BI19 BI20 BI21 BI22

1 off Y Y Y 2 disconnected and stand-by Y Y 3 disconnected and available Y Y 4 disconnected and authorized Y Y Y 5 starting and synchronizing Y Y 6 connected and idle Y Y Y 7 connected and generating Y Y Y 8 connected and consuming Y Y Y 9 stopping Y Y 10 disconnected and blocked Y Y Y disconnected and in 11 Y Y Y maintenance 12 ceased to energize Y Y 13 failed Y Y

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Of f Failed state - Disconnected & in from any other Maintenance state due to er r or s

[Turn Off] [Go to Standby] [Turn On] [Go to Maintenance] [Connect to Disconnected & Disconnected & Logic 2 Logic 4 Disconnected, grid] Starting & Sta ndby Av a ila ble Available, & Synchronizing Logic 5 Logic 7 Logic 1 Author ized

[Get blocked]

[Disconnect command or Logic 6 [Get emergency disconnect] unblocked] Stopping Logic 3 Disconnected & [Cease to energize] Cea sed to Blocked [Disconnect command or Connected & Idle emergency disconnect] Ener gize [Return to service]

[Disconnect command or emergency disconnect] [Start exporting active power] [Stop exporting [Disconnect command or active power] emergency disconnect] Logic 3 [Start importing active power] Logic 3 Connected and gener a ting [Stop importing active power]

[Start exporting active power] [Start importing active power]

Connected and consuming active power

Definitions of Logic connections: ⦁ Logic1: allows you to transition from disconn stdby to disconn & avail based on internal conditions. Ex. Genset is started. It may take a few second to get from disconn & standby to disconn & available.

⦁ Logic2: based on the authorization status which allows you to transition from disconn avail to disconn & auth.

⦁ Logic3: Many conditions forcing you to get disconnected because you are (effectively) unauthorized or blocked or disconnected by external means. Ex. Large EESS system can be blocked by an internal reason or fire in the site.

⦁ Logic4: allows you to transition from disconn avail to disconn & stdby based on internal conditions. ex. Change in voltage exceeds limits. Or a Genset is stopped. Logic4 is equal to inverse of Logic1.

⦁ Logic5: based on the authorization status which allows you to transition from disconn & auth to disconn & avail. Ex. The authorization signal is withdrawn. Logic5 is equal to inverse of Logic2.

⦁ Logic6: starts the synchronization and connection steps after a specific connect command

⦁ Logic7: is an automatic connect command which starts the synchronization and connection steps

Figure 8 - IEC 61850-7-420 DER State Diagram (Draft)

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2.4.7 Time Synchronization Function Time synchronization shall take place using the standard methods described in the DNP3 specifications. (Refer to section 10.3 of IEEE 1815-2012). Note that the method varies depending on whether communications takes place over a serial link or a local-area-network (LAN). Implementations of this profile must support the DNP3 time synchronization methods, but other methods (e.g. SNTP, NTP, IRIG- B) are also permitted. The master shall be configurable to permit DNP3 time synchronization to be disabled if such other methods are used.

2.4.8 Event/History Logging Function Logging is specified in IEC 61850 but is optional in this profile. The following information should be logged: • All errors or failures • All startup and shutdown actions • All control actions • All responses to control actions • All limit violations, including returns within limits Outstations wishing to create event logs may use the DNP3 Data Set mechanism as defined in Volume 2, Part 2, of the DNP3 Specification. This mechanism allows the outstation to define the format of the event logs it will report, and describe them to the master so the master can interpret them correctly. The following rules shall apply: 1. The data sets for PV event logs shall be defined by the outstation, not the master. Outstations are not required to permit masters to dynamically define PV event log data sets. 2. The outstation shall provide a Data Set Descriptor object (g86) for each PV event log that the master can read to find out what it contains. 3. The PV event logs shall be Event Data Sets (g88), not Static Data Sets (g87). 4. Use of Data Set Prototype objects (g85) by the outstation is not required but masters must be able to interpret them. 5. The outstation shall initially assign PV event logs to Class 1 on startup, although the master may later re-assign it using the ASSIGN CLASS function code. 6. The Data Set Descriptor for each data set shall include human-readable text descriptions of each element 7. PV event log data sets shall be read-only. 8. Once the PV event log data set has been read and the response has been confirmed by the master, the outstation is not required to retain the event information. It is assumed that the master is storing the event log as it is retrieved.

2.5 Emergency Modes The modes listed in this section describe methods by which DERs may support the operation of power utilities during an emergency condition such as outage or instability.

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2.5.1 Low/High Voltage Ride-Through Mode The steps in Table 33 describe how to cause the DER to determine when to disconnect or remain connected during a voltage excursion. Figure 9 illustrates an example (from a draft of IEEE Std 1547) of typical voltage ride-through requirements. In general, large voltage excursions are “tolerated” for only very short intervals, while smaller excursions cause disconnection after a much longer interval. Figure 10 illustrates how these requirements can be configured in the DER as curves (see 2.3.3 for a discussion of how curves are defined). Table 32 lists the four possible High-Voltage Ride-Through (HVRT) and Low-Voltage Ride-Through (LVRT) curves which can be selected for definition by writing the corresponding value to Curve Mode Type (AO245). Table 32 – Low/High Voltage Ride-Through Curve Mode Types Value Name Description “Outside” this curve the DER must trip. If it trips, it must go through <9> HVRT Must Trip the “return to service” steps as described in 2.4.5. Outside this curve the DER must stop discharging/generating but be prepared to resume discharging/generating so if conditions return to being “inside” the curve. <10> HVRT Momentary Cessation At some point between this curve and the “must trip” curve the DER may choose to trip on its own. Inside this curve the DER continues normal operation. “Outside” this curve the DER must trip. If it trips, it must go through <11> LVRT Must Trip the “return to service” steps as described in 2.4.5. Outside this curve the DER must stop discharging/generating but be prepared to resume discharging/generating so if conditions return to being “inside” the curve. <12> LVRT Momentary Cessation At some point between this curve and the “must trip” curve the DER may choose to trip on its own. Inside this curve the DER continues normal operation.

The specific shapes of the curves for any given application are provided by utilities, reflecting both regulatory and utility requirements. Because these curves directly affect the safety and reliability of the power grid, it is possible the outstation may not permit the master to write them using DNP3, only read them. If the outstation supports it, the steps necessary to define these curves are listed in Table 33. Some rules apply: 1. The curves are not permitted to cross, and in general must have some clearance between them to account for tolerances and noise. 2. All the voltages in a HVRT curve must be greater than the nominal voltage (>100%), describing a curve for evaluating swells. 3. All the voltages in an LVRT must be less than the nominal voltage (<100%), describing a curve for evaluating sags. 4. The outstation shall reject any attempt to enable an illegal curve with a PARAMETER ERROR internal indication. The timeout parameters described in 2.3.1 and the filtering parameters described in 2.3.4 do not exist for ride-through modes. All the curves are assumed to extend horizontally to zero seconds from the first point defined in the array and horizontally to the right beyond the right-most point in the array.

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All times in the curves are defined in milliseconds. The voltages in the curves are defined as:

Percent Voltage Voltage at the Curve Point = x 100 % (Y-Value of Curve) Nominal Voltage

Where the outstation will calculate Nominal Voltage as follows when the curve is executed.

Nominal Voltage = Reference Voltage (AO0) + Reference Voltage Offset (AO1)

NOTE: The outstation reports the protection status of this mode (started, operated blocked) in BI52 through BI57.

Figure 9 – Example of Voltage Ride-Through Requirements

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Operation Areas Continuous / Mandatory Operation Continuous Operation / Mandatory Operation

Momentary Momentary Cessation Momentary Cessation Cessation May Ride Must Remain Thru or Trip Connected ** Must Trip Must Trip Must Trip

** IMPORTANT: This curve would not actually be configured in the device. It is used for testing only. There is no curve by this name.

Figure 10 – Ride-Through Curves and Areas Between Curves

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Table 33 – Steps to define the LVRT and HVRT modes using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Select which curve to edit Required Direct Operate / Response AO AO244 AI328 Specify the Curve Mode Type as 2. Optional Direct Operate / Response AO AO245 AI329 described in Table 32. Specify that the Independent (X- 3. Optional Direct Operate / Response AO AO247 AI331 Value) units are <4> Time Specify the Dependent (Y-Value) 4. units are <8> Percent of nominal Optional Direct Operate / Response AO AO248 AI332 Voltage Set the Reference Voltage if it is 5. Optional Direct Operate / Response AO AO0 AI29 not already set Set the Reference Voltage Offset 6. Optional Direct Operate / Response AO AO1 AI30 if it is not already set Set time (X-Values) for each curve point to the number of AO249, AI333, 7. Optional Direct Operate / Response AO milliseconds from the start of the AO251 … AI335 … event Set active power (Y-Values) for each curve point to the voltage AO250, AI334, 8. Optional Direct Operate / Response AO as a percentage of the nominal AO252 … AI336 … voltage Set number of points used for the 9. Optional Direct Operate / Response AO AO246 AI330 curve. Identify the meter used to 10. measure the voltage. By default Optional Direct Operate / Response AO AO22 AI71 this is the System Meter (ID = 0) AO23, AI73, If the curve is a “must trip” curve, AO24, AI74, 11. identify the index of the curve Optional Direct Operate / Response AO AO26, AI75, being used AO27 AI76 Repeat steps 2 through 11 for the 12. Optional See above remaining curves Enable the Low/High Voltage Select / Response, 13. Required BO BO12 BI64 Ride-Through Mode Operate / Response

2.5.2 Low/High Frequency Ride-Through Mode – NEW The steps in Table 35 describe how to cause the DER to determine when to disconnect or remain connected during a frequency excursion. In a manner similar to that described in 2.5.1, and as listed in Table 34 there are four curves defining behavior of this mode.

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Table 34 – Low/High Frequency Ride-Through Curve Mode Types Value Name Description “Outside” this curve the DER must trip. If it trips, it must go through <13> HFRT Must Trip the “return to service” steps as described in 2.4.5. Outside this curve the DER must stop discharging/generating but be prepared to resume discharging/generating so if conditions return to being “inside” the curve. <14> HFRT Mandatory Operation At some point between this curve and the “must trip” curve the DER may choose to trip on its own. Inside this curve the DER continues normal operation. “Outside” this curve the DER must trip. If it trips, it must go through <15> LFRT Must Trip the “return to service” steps as described in 2.4.5. Outside this curve the DER must stop discharging/generating but be prepared to resume discharging/generating so if conditions return to being “inside” the curve. <16> LFRT Mandatory Operation At some point between this curve and the “must trip” curve the DER may choose to trip on its own. Inside this curve the DER continues normal operation.

Table 35 – Steps to define the LFRT and HFRT modes using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point Direct Operate / 1. Select which curve to edit Required AO AO244 AI328 Response Specify the Curve Mode Direct Operate / 2. Type as described in Table Optional AO AO245 AI329 Response 34 Specify that the Independent Direct Operate / 3. Optional AO AO247 AI331 (X-Value) units are <4> Time Response Specify the Dependent (Y- Value) units are <9> Direct Operate / 4. Frequency as a percent of Optional AO AO248 AI332 Response Nominal Grid Frequency (ECPNomHz) Set the Nominal Grid Direct Operate / 5. Frequency if it is not already Optional AO AO2 AI31 Response set Set time (X-Values) for each curve point to the number of Direct Operate / AO249, AI333, 6. Optional AO milliseconds from the start of Response AO251 … AI335 … the event Set active power (Y-Values) for each curve point to the Direct Operate / AO250, AI334, 7. Optional AO frequency as a percentage Response AO252 … AI336 … of the nominal frequency Set number of points used Direct Operate / 8. Optional AO AO246 AI330 for the curve. Response Identify the meter used to measure the frequency. By Direct Operate / 9. Optional AO AO27 AI77 default this is the System Response Meter (ID = 0) AO28, AO78, Identify the index of the Direct Operate / AO29, AI79, 10. Optional AO curve being used Response AO30, AI80, AO31 AO81

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Data Point Read-back Step Description Optionality Function Codes Type Number Point

Enable the Low/High Select / Response, 11. Frequency Ride-Through Required BO BO13 BI65 Mode Operate / Response

NOTE: The outstation reports the protection status of this mode (started, blocked, operated) in BI58 through BI63.

2.5.3 Frequency-Watt Mode – NEW The steps in Table 36 describe how to cause the DER to absorb or produce additional Watts in proportion to the measured difference from the nominal grid frequency. Its purpose is to influence the frequency to return to normal. Most often this is implemented by reducing Watts when frequency increases or increasing Watts when the frequency decreases. The mode may cause the DER to reduce generated Watts to the point where it no longer produces Watts, but begins charging, or vice versa. Figure 11 illustrates the operation of this mode in the case in which the DER is generating active power when the frequency begins deviating. Figure 12 illustrates the case in which the DER is charging storage when the frequency begins deviating.

HiHzStr to start to decreasing watts as per the Legend: P1-P2 gradient at the P1 frequency, then the Active power boundaries, defining P2-P3 gradient starting at the P2 frequency maximums and gradients when generating. The P3-P4 gradient is used Frequencies that, if exceeded, activate when consuming the F-W function Requested active power per frequency, WMax: Max Generating Power P1 indicating “not to exceed” limit

Areas where the F-W function is active

Zone 1: Generating, Hysteresis paths

High Frequency g n i t

a P2 r P2-P3 gradient, = HiWGra = % of WMax per HZ e n e G

–

ReqWSet = Wref+ %WMax/Hz *(f-HiHzStr), r

e where “f” is the actual frequency w o P

e v i t c A HiHzStop

n System Frequency i m

u P3-P4 gradient, or s

n HiWChaGra o C

–

r e

w Hz for tripping based

o on frequency ride- P

e through criteria

v Zone 3: Consuming, i t

c High Frequency A P4 WChaMax: Max Consuming Power

Figure 11 – Frequency-Watt Mode (started when generating)

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The active power change resulting from this mode is in addition to any active power produced or absorbed by other modes. The DER shall not begin altering its active power output until it reaches a Starting Frequency (AO62 if the frequency is too high or AO66 if the frequency is too low, shown as HiHzStr and LoHzStr in Figure 11 and Figure 12). This condition must be satisfied for a specified Start Delay Time (AO70) before the mode becomes active. Similarly, the DER shall not stop altering its active power until the frequency returns to a specified Stopping Frequency (AO63 or AO67, shown as HiHzStop or LoHzStop in the figures) close to the Nominal Grid Frequency (AO2). This condition must be satisfied for a specified Stop Delay Time (AO71) before the mode becomes inactive. The rate at which the DER changes its active power in response to the frequency deviation is specified by four Gradients, one for when the frequency is low (AO68) and one for when it is high (AO64), for charging and discharging which are signed quantities. These are shown as LoWGra and HiWGra in the figure. A negative value in any of the gradients means the DER reduces active power as frequency increases.

Frequency-Watt Additional Watts as a Percentage of High Discharging / Maximum Discharging / Generation Power (AI32) Generating = Gradient Percent Difference from Nominal Grid Frequency (AO2) (AO64) Frequency-Watt Additional Watts as a Percentage of High Charging Maximum Charging Power (AI33) = Gradient Percent Difference from Nominal Grid Frequency (AO2) (AO65) Frequency-Watt Additional Watts as a Percentage of Low Discharging / Maximum Discharging / Generation Power (AI32) Generating = Gradient Percent Difference from Nominal Grid Frequency (AO2) (AO68) Frequency-Watt Additional Watts as a Percentage of Low Charging Maximum Charging Power (AI33) = Gradient Percent Difference from Nominal Grid Frequency (AO2) (AO69)

If the master enables the Use Hysteresis binary output (BO34), the DER active power output remains at its most extreme level even when the frequency begins to correct itself, until the frequency returns to normal, as illustrated by the dotted green arrows in Figure 11. If the master disables Snapshot of Power (BO35), the DER will not necessarily begin altering its active power output when the HiHzStr or LoHzStr limits are exceeded. It will maintain its output within the area bounded by the blue line in Figure 11, but will not follow the dashed red line. Instead, its behavior may be similar to that shown for Volt-Watt mode in Figure 28 on page 219.

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Legend: HiHzStr to start to decreasing watts as Active power boundaries, defining LoHzStr to start increasing watts per the P2-P3 gradient when generating maximums and gradients as per the P1-P6 gradient when Hz for tripping based and the P3-P4 gradient when consuming Frequencies that, if exceeded, activate generating, and the P5-P6 the F-W function on frequency ride- gradient when consuming through criteria WMax: Max Generating Power Requested active power per frequency, P1 P2 indicating “not to exceed” limit

Areas where the F-W function is active

Zone 2: Generating, Zone 1: Generating, Hysteresis paths Low Frequency High Frequency

P2-P3 gradient, = HiWGra = % of WMax per HZ

g n i t a r e

n P1-P6 gradient, e

G or LoWGra

–

r e w

o P6 P3 P

e v i t System Frequency c WRef at A

- HiHzStr P3-P4 gradient, or

g Nominal

n HiWChaGra i frequency

m P5-P6 u

s gradient, or n

o LoWChaGra Zone 4: Consuming, Hz for tripping based C

Low Frequency

on frequency ride- WRef at Active Power Input through criteria LoHzStr (Consuming) Zone 3: Consuming, High Frequency P5 P4 WChaMax: Max Consuming Power

Figure 12 – Frequency-Watt Mode (started when charging)

The master may also specify a Maximum Watts Change Rate (AO79) which applies regardless of the gradients. There is another Frequency-Watt mode, described in 2.6.8, that uses configured curves rather than gradients, but the functionality is essentially the same. Table 36 – Steps to enable Frequency-Watt mode using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point If not already established, set the 1. Optional Direct Operate / Response AO AO2 AI31 Nominal Grid Frequency 2. Set priority of this mode Optional Direct Operate / Response AO AO57 AI115 3. Set enabling time window Optional Direct Operate / Response AO AO58 AI116 4. Set enabling ramp time Optional Direct Operate / Response AO AO59 AI117 5. Set enabling reversion timeout Optional Direct Operate / Response AO AO60 AI118 Identify the meter used to measure the frequency. By 6. Optional Direct Operate / Response AO AO61 AI119 default this is the System Meter (ID = 0) 7. Set the High Starting Frequency Optional Direct Operate / Response AO AO62 AI121 8. Set the High Stopping Frequency Optional Direct Operate / Response AO AO63 AI122 Set the High Discharging 9. Optional Direct Operate / Response AO AO64 AI123 Gradient 10. Set the High Charging Gradient Optional Direct Operate / Response AO AO65 AI124 11. Set the Low Starting Frequency Optional Direct Operate / Response AO AO66 AI125 12. Set the Low Stopping Frequency Optional Direct Operate / Response AO AO67 AI126 13. Set the Low Discharging Gradient Optional Direct Operate / Response AO AO68 AI127 14. Set the Low Charging Gradient Optional Direct Operate / Response AO AO69 AI128

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Data Point Read-back Step Description Optionality Function Codes Type Number Point 15. Set the Start Delay Optional Direct Operate / Response AO AO70 AI129 16. Set the Stop Delay Optional Direct Operate / Response AO AO71 AI130 Set the Ramp Up and Down Time AO72, AI131, 17. Optional Direct Operate / Response AO Constants AO73 AI132 AO74, AI133, Set the Charging and Discharging AO75, AI134, 18. Optional Direct Operate / Response AO Up and Down Ramp Rates AO76, AI135, AO77 AI136 Set the Hi and Low Return AO78, AI137, 19. Optional Direct Operate / Response AO Gradients AO79 AI138 Set the minium and maximum AO80, AI140, 20. State of Charge to be used by Optional Direct Operate / Response AO AO81 AI141 this mode 21. Enable or Disable Hysteresis Optional Direct Operate / Response BO BO34 BI86 Enable or Disable Snapshot of 22. Optional Direct Operate / Response BO BO35 BI87 Power Select / Response, 23. Enable Frequency-Watt Mode Required BO BO16 BI68 Operate / Response

2.5.4 Dynamic Reactive Current Support Mode The steps in Table 37 describe how to cause the DER to support the stabilization of the electrical system by providing additive reactive current in proportion to the instantaneous difference from a moving average of the measured voltage.

2.5.4.1 Basic Operation Figure 13 illustrates how the outstation calculates a continuous Moving Average Voltage (AI89) over a specified number of seconds known as the Filter Time (AO42).

V Average over FilterTms

Delta Voltage @ time = Present (negative value

shown) Voltage Voltage

FilterTms

Time Present

Figure 13 – Delta Voltage Calculation

The difference between this Moving Average Voltage and the currently measured voltage at any moment is calculated as:

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Percent Delta Measured Voltage – Moving Average Voltage (AI89) = x 100 % Voltage (AI90) Reference Voltage (AO0)

The meter used to measure voltage is specified in AO36. It is a local matter whether the designated measured voltage is one of the per-phase voltages or an average or total of these voltages, provided the moving average voltage is calculated the same way. Figure 14 illustrates how the outstation provides reactive current, either inductive or capacitive, in proportion to the Delta Voltage at any moment, in addition to any reactive current that may be applied by other functions such as the static Volt/VAR curve functions.

DbVMin DbVMax

) Deadband ARtg

ArGraSag Capacitive Delta Voltage (% of VRef)

Moving ArGraSwell Average of

Voltage

Inductive Additional Reactive Current (% (% of Current Reactive Additional

Figure 14 – Dynamic Current Support Function

The master specifies the curve in Figure 14 using four values. Firstly, it specifies two voltage thresholds that define a “Deadband” in which the outstation provides no reactive current support. When the Delta Voltage is below the Deadband Minimum Voltage (AO38) a “sag” is said to be occurring. When the Delta Voltage is above the Deadband Maximum Voltage (AO39) a “swell” is said to be occurring. The deadbands are expressed as a percentage of the reference voltage, as the Delta Voltage is. Secondly, the master specifies two gradients. The gradients are defined as follows:

Percent Reactive Additional Reactive Current to Supply (Amps) = x 100 % Current Maximum Current Rating (AI19 or AI20 or see Table 24)

Reactive Current Percent Reactive Current = Support Gradient Percent Delta Voltage

The outstation applies the Reactive Current Support Gradient for Sags (AO40) when the Delta Voltage is negative and applies the Reactive Current Support Gradient for Swells (AO41) when the Delta Voltage is positive.

2.5.4.2 Alternative Gradient Option

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The master can also specify the alternate curve shape shown in Figure 15 by selecting <1> Gradients reach 0 at the Moving Average Voltage as the Dynamic Reactive Current Support Gradient Mode (AO37). The normal curve shape shown in Figure 14 is selected using <2> Gradients reach 0 at the Voltage deadbands. Note that the current support follows different paths if the Delta Voltage is increasing or decreasing.

DbVMin DbVMax )

Deadband ARtg

ArGraSag

Capacitive Delta Voltage (% of VRef)

ArGraSwell Moving Average of

Voltage

Additional Reactive Current (% (% of Current Reactive Additional Inductive

Figure 15 – Alternate Dynamic Current Gradient Mode

2.5.4.3 Event-Based Behavior Option The master can enable “event-based” dynamic current support by writing to the appropriate binary output (BO33). Figure 16 illustrates this behavior. When this feature is enabled, a voltage sag or swell “event” is considered to start when the voltage exceeds one of the deadband thresholds (shown as time t0).

Dynamic Reactive Current Support DbVMax Moving Average of Time Voltage (0% Delta) Dead-band (No Dynamic Reactive Current Support) t2 DbVMin

) t0

t1 VRef

HoldTmms VAverage

Dynamic Reactive Current Support

Delta Voltage Delta

Relative to to Relative (expressed in % % in (expressed

Figure 16 – Event-Based Dynamic Current Support

When this option is activated, the Moving Average Voltage and any reactive current levels that might exist due to other functions - such as the static Volt-VAr mode – are frozen at t0 when the event begins

Page 202 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs) and are not free to change again until t2 when the event ends. The additional reactive current level specified by this function (as shown in Figure 14 or Figure 15) continues to vary throughout the event and is added to any frozen reactive current. Assuming the voltage returns within the deadband at t1, additional reactive current support continues until a specified Hold Time (AO46) has elapsed (t2 = t1 + Hold Time). If Event-Based Behavior is not enabled, the Hold Time is not applied, freezing of the Moving Average Voltage and static VARs does not occur, and the gradient curve in either Figure 14 or Figure 15 is applied continuously

2.5.4.4 Blocking Zone Option The master may define a “blocking zone” in which no dynamic reactive current support is applied, as illustrated in Figure 17. If the absolute voltage, expressed as a percentage of the reference voltage, drops below a specified Block Zone Voltage (AO43), the outstation shall stop applying support (time t0). The outstation shall not return to providing support until the voltage rises above the Hysteresis Block Zone Voltage (AO44) (time t1). The master can also specify that regardless how low the voltage sags, dynamic reactive current support will be applied for at least a guaranteed Block Zone Time (AO45) after the voltage exceeds the deadband

(i.e. an “event” has begun). ) 100%

VRef (=VRef) Dynamic Reactive Current Support Zone

BlkZnV+ HysBlkZnV Hysteresis BlkZnV t0 t1

No Dynamic Reactive Current Support Voltage (expressed in % % in (expressed Voltage Time 0% BlkZnTmms

Figure 17 – Settings to Define a Dynamic Reactive Current Blocking Zone

All the steps marked as “Required” in Table 37 are required the first time the function is enabled. If all the settings have already been established, only the final step is required.

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Table 37 – Steps to enable Dynamic Reactive Current Mode Read- Data Point Step Description Optionality Function Codes back Type Number Point 1. Set priority of this mode Optional Direct Operate / Response AO AO32 AI83 2. Set enabling time window Optional Direct Operate / Response AO AO33 AI84 3. Set enabling ramp time Optional Direct Operate / Response AO AO34 AI85 4. Set enabling reversion timeout Optional Direct Operate / Response AO AO35 AI86 Identify the meter used to 5. measure the voltage. By default Optional Direct Operate / Response AO AO36 AI87 this is the System Meter (ID = 0) Set the Gradient Mode to select 6. Required Direct Operate / Response AO AO37 AI91 the curve shape Set the Deadband Minimum 7. Required Direct Operate / Response AO AO38 AI92 Voltage Set the Deadband Maximum 8. Required Direct Operate / Response AO AO39 AI93 Voltage Set the Reactive Current Support 9. Required Direct Operate / Response AO AO40 AI94 Gradient for Sags Set the Reactive Current Support 10. Required Direct Operate / Response AO AO41 AI95 Gradient for Swells Set the Filter Time for the Moving 11. Required Direct Operate / Response AO AO42 AI96 Average Voltage in seconds Enable Event-Based Reactive 12. Current Support if required. It Optional Direct Operate / Response BO BO33 BI85 shall default to Disabled. Set the Hold Time in milliseconds 13. if Event-Based Reactive Current Optional Direct Operate / Response AO AO46 AI100 Support is required. Set the Block Zone Voltage if 14. required. Otherwise it shall Optional Direct Operate / Response AO AO43 AI97 default to zero. Set the Hysteresis Block Zone 15. Voltage if required. Otherwise it Optional Direct Operate / Response AO AO44 AI98 shall default to zero. Set the Block Zone Time in 16. milliseconds if required. Optional Direct Operate / Response AO AO45 AI99 Otherwise it shall default to zero. Enable Dynamic Reactive Current Select / Response, 17. Required BO BO14 BI66 Mode Operate / Response

2.5.5 Dynamic Volt-Watt Mode The steps in Table 38 describe how to cause the DER to dynamically absorb or produce additional Watts in proportion to the instantaneous difference from a moving average of the measured voltage. This function utilizes the same basic concepts and settings as the Dynamic Reactive Current function described in section 2.5.3, but uses active power as an output rather than reactive current. Figure 18 illustrates how the outstation calculates a continuous Moving Average Voltage over a specified number of seconds known as the Dynamic Volt-Watt Filter Time (AO54).

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VAverage over

FilterTms )

Vref Delta Voltage at Present (% Vref)

FilterTms Voltage at ECP (% (% ECP at Voltage

Time Present

Figure 18 – Delta Voltage Calculation for Dynamic Volt-Watt Mode

The difference between this Moving Average Voltage and the currently measured voltage at any moment is calculated as:

Percent Delta Measured Voltage – Moving Average Voltage = x 100 % Voltage Reference Voltage (AO0)

It is a local matter whether the designated measured voltage is one of the per-phase voltages or an average or total of these voltages, provided the moving average voltage is calculated the same way. Like the Dynamic Reactive Current Mode, in Dynamic Volt-Watt mode the master can read the present Moving Average Voltage (AI108) and the Percent Delta Voltage (AI109) Figure 19 illustrates how the outstation either generates or absorbs active power, in proportion to the Delta Voltage at any moment, in addition to any active power produced or absorbed by other functions.

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DbVLo DbVHi Dynamic Deadband

Watt Delta Voltage ) Gradient (Present Voltage Minus WMax Moving Average % VRef)

Dynamic Moving Watt Average of Gradient

Voltage at Additional Watts (% (% Additional Watts ECP

Figure 19 – Dynamic Volt-Watt Mode

The master specifies the curve in Figure 19 using three values. Firstly, it specifies two voltage thresholds that define a “deadband”. When the Percent Delta Voltage is above the Dynamic Volt-Watt Lower Deadband (AO55) and below the Dynamic Volt-Watt Upper Deadband (AO56) the outstation shall not generate or absorb additional active power. The deadband values are specified as percentages of the Reference Voltage, as is the Percent Delta Voltage. Secondly, the master specifies a gradient, defined as follows:

Percent Additional Watts Supplied = x 100 % Additional Watts Maximum Active Power (AI32, AI33)

Dynamic Volt-Watt Percent Additional Watts = Gradient (AO53) Percent Delta Voltage

This active power will be in addition to the active power generated by any other functions active on the outstation. Unlike the Dynamic Reactive Current function, the outstation applies the same gradient regardless of whether the Percent Delta Voltage is positive or negative. The Dynamic Volt-Watt Gradient is a signed quantity. A negative value will cause generation at low voltages and charging at high voltages. A different value may be used for Maximum Active Power depending on whether the outstation is charging or discharging.

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Table 38 – Steps to enable Dynamic Volt-Watt mode using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point If not already established, set the 1. Optional Direct Operate / Response AO AO0 AI29 Reference Voltage If not already established, set the 2. Optional Direct Operate / Response AO AO1 AI30 Reference Voltage Offset 3. Set priority of this mode Optional Direct Operate / Response AO AO48 AI102 4. Set enabling time window Optional Direct Operate / Response AO AO49 AI103 5. Set enabling ramp time Optional Direct Operate / Response AO AO50 AI104 6. Set enabling reversion timeout Optional Direct Operate / Response AO AO51 AI105 Identify the meter used to 7. measure the voltage. By default Optional Direct Operate / Response AO AO52 AI106 this is the System Meter (ID = 0) Set the Dynamic Volt-Watt 8. Optional Direct Operate / Response AO AO53 AI110 Gradient Set the Dynamic Volt-Watt Filter 9. Optional Direct Operate / Response AO AO54 AI111 Time Set the Dynamic Volt-Watt Lower 10. Optional Direct Operate / Response AO AO55 AI112 Deadband Set the Dynamic Volt-Watt Upper 11. Optional Direct Operate / Response AO AO56 AI113 Deadband Select / Response, 12. Enable Dynamic Volt-Watt mode Required BO BO15 BI67 Operate / Response

2.6 Active Power Modes The modes described in this section control the active power (Watts) output of the DER under “non- emergency” conditions.

2.6.1 Active Power Limit Mode The steps in Table 39 describe how to set the maximum generation or charging level of the DER at the electrical coupling point as a percentage of its nominal capacity. The outstation shall start the time window, reversion timeout, and ramp time at the moment the master successfully operates the mode enable command. The setpoints for maximum active power generation are calculated as follows:

Active Power Limit Desired Maximum Active Power (Watts) Charge Setpoint = x 100 % (AO87) Maximum Active Charging Power (AI33)

Active Power Limit Desired Maximum Active Power (Watts) Generation Setpoint = x 100 % (AO88) Maximum Active Generation Power (AI32)

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Table 39 – Steps to enable Active Power Limit mode using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set priority of this mode Optional Direct Operate / Response AO AO82 AI142 2. Set enabling time window Optional Direct Operate / Response AO AO83 AI143 3. Set enabling ramp time Optional Direct Operate / Response AO AO84 AI144 4. Set reversion timeout Optional Direct Operate / Response AO AO85 AI145 Identify the meter used to measure the active power. 5. Optional Direct Operate / Response AO AO86 AI146 By default this is the System Meter (ID = 0) Retrieve Maximum Active n/a AI32 and 6. Power Capability (Charging Optional Read / Response AI AI33 and Discharging) Set maximum output in AO87 and AI148 and 7. percent of nominal Watts Required Direct Operate / Response AO AO88 AI149 (Charging and Generating) Enable Active Power Limit Select / Response, 8. Required BO BO17 BI69 mode and receive response Operate / Response

2.6.2 Charge/Discharge Storage Mode The steps in Table 41 describe how to directly manage the charging and discharging of the storage portion of the DER. The outstation shall start the time window, reversion timeout, and ramp time at the moment the master successfully operates the mode enable command. When discharging, the setpoint is calculated as follows:

Charge/Discharge Active Desired Discharge Rate (Watts) = x 100 % Power Target (AO93) Maximum Active Generation Power (AI32)

When charging, the setpoint is calculated as follows:

Charge/Discharge Active Desired Charge Rate (Watts) = x -100 % Power Target (AO93) Maximum Active Charging Power (AI33)

Note that the setpoint is negative when charging is desired. The limits of DER charging or discharging are expressed differently depending upon what is important to different types of users. The vendor of a storage system is concerned about the actual capacity of the storage, while an operator is only interested in what capacity is available to be used. The actual capacity may change over time as the storage system is used. Therefore, as illustrated in Figure 20, three different capacity parameters are reported by the outstation: • The Nameplate Storage Actual Energy Capacity (AI16) represents the original physical limit of the storage system (not shown in the figure). • The Storage Effective Actual Energy Capacity (AI17) represents the present physical limit of the storage system. • The Storage Usable Energy Capacity (AI18). The usable capacity is what users are permitted to have access to, which is based on the decisions of the storage manufacturers or owner/operators.

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Effective Actual Energy

Fully Charged (100% of Actual Capacity) Usable Energy Charged (100% of Usable Capacity) Maximum Usable State of Charge (% of Actual Capacity) Maximum Reserve Percentage* (% of Usable Capacity) Hatched Actual State of Charge Blue orange Usable State of Charge* (% of Effective Actual Capacity) (% of Usable Capacity)

Effective Actual Energy Capacity Usable Energy Capacity* (Watt-hrs) (Watt-hrs) Minimum Reserve Percentage* Minimum Usable State of Charge (% of Usable Capacity) (% of Actual Capacity) Depleted Fully Depleted (0% of Usable Energy Capacity) (0% of Actual Energy Capacity) Figure 20 – Relationships Between Storage Parameters

When charging, the outstation will continue to charge at the selected rate until the Maximum Reserve for Storage (percent full) is reached (AO101). When discharging, the outstation will continue to discharge at the selected rate until the Minimum Reserve for Storage (percent full) is reached (AO100). NOTE: These reserves also apply in any other modes that involve charging and discharging active power. If the Charge/Discharge Active Power Target (AI35) is changing as a result of a schedule or a curve, the amount this setpoint can change per minute is limited by one of several parameters, depending on the direction of the change and the value of a BO as shown in Table 40. Table 40 – Use of Ramp Rates or Time Constants to Limit Charge/Discharge Mode Setting of Charge/Discharge Charging Discharging Mode – Use Ramp Rates (BO38) Point Name Num Point Name Num Charge/Discharge Charge AO98, Charge/Discharge Discharge AO96, <1> Ramp rates should be used Ramp Up Rate AI159 Ramp Up Rate AI157 Charge/Discharge Charge AO99, Charge/Discharge Discharge AO97, Ramp Down Rate AI160 Ramp Down Rate AI158 Charge/Discharge Time AO94, Charge/Discharge Time AO94, Constant Ramp Up Time AI155 Constant Ramp Up Time AI155 <0> Ramp times should be used Charge/Discharge Time AO95, Charge/Discharge Time AO95, Constant Ramp Down Time AI156 Constant Ramp Down Time AI156

Charging and discharging active power is also limited by the Maximum Apparent Discharging Power (AI36) and Maximum Apparent Charging Power (AI37) The present System Available State of Charge can be read by the master at any time, either as a percentage of actual capacity (AI47) or as a percentage of usable capacity (AI48) The Capacity Ratings may be set in units of either Amp-hrs or Watt-hrs, as defined in the Storage Capacity Units point (BO8). Note that using Amp-hrs as a measure of storage capacity assumes a nominal DC voltage. The documentation for the storage system shall describe how this assumption is calculated.

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NOTE: All of these parameters apply to the behavior of the DER as a whole, not any individual storage units within the DER. Table 41 – Steps to charge or discharge storage using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set priority of this mode Optional Direct Operate / Response AO AO89 AI150 2. Set enabling time window Optional Direct Operate / Response AO AO90 AI151 3. Set enabling ramp time Optional Direct Operate / Response AO AO91 AI152 4. Set enabling reversion timeout Optional Direct Operate / Response AO AO92 AI153 Select whether to use Ramp Rates 5. Optional Direct Operate / Response BO BO38 BI90 or Time Constants Set the Ramp Rates or Time See See 6. Optional Direct Operate / Response AO Constants Table 40 Table 40 Set Minimum Reserve for Storage 7. (percent of Battery Capacity Optional Direct Operate / Response AO AO100 AI161 Rating) Set Maximum Reserve for Storage 8. (percent of Battery Capacity Optional Direct Operate / Response AO AO101 AI162 Rating) Set discharge/charge Active Power 9. Target . Positive is discharging, Required Direct Operate / Response AO AO93 AI154 negative is charging. Enable charge/discharge mode Select / Response, 10. Required BO BO18 BI70 and receive response Operate / Response

2.6.3 Coordinated Charge/Discharge Management Mode – NEW The steps in Table 42 describe how to cause the DER to charge storage up to a specified Target State of Charge by a specified Target Time, as might be required when charging electric vehicles. The intent is to allow the DER to choose the most cost-effective manner to achieve these targets. For instance, Figure 21 illustrates how the DER could perform maximum charging when the energy price is low and decrease the rate of charging during higher demand prices, while still meeting the target state of charge before the required time.

d e h c a e R

e g r a h C

f o

e t a t S

t e g r a T

Low Energy Price Higher Demand Price

Figure 21 – Coordinated Charge/Discharge Mode

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The target state of charge is entered as a percentage of the Nameplate Storage Usable Capacity (AI18) as discussed in 2.6.2. The master shall set the Target Time as two separate analog outputs, representing days since Jan 1, 1970 and milliseconds within the day. The master may also request constraints on the charging solution chosen by the DER using AO109 through AO114, as follows: • Coordinated Charge/Discharge Energy Request (area under the curve) • Coordinated Charge/Discharge Minimum Charging Duration • Coordinated Charge/Discharge Date of Reference • Coordinated Charge/Discharge Time of Reference • Coordinated Charge/Discharge Duration at Maximum Charge Rate • Coordinated Charge/Discharge Duration at Maximum Discharge Rate The DER shall validate these settings to verify they are compatible with each other, and reject changes that are not possible. Regardless of which of these analog outputs it permits to be written, DER shall report its chosen values of these constraints in the corresponding analog inputs (AI170 through AI175) Charging in this mode continues to be limited by the Maximum Charging Ramp Up Rate (AI64) and the Maximum Charging Ramp Down Rate (AI65) for the system. Other active power modes may be in effect at the same time as this mode, according to configured priorities. These priorities may affect the ability of the DER to meet the target state of charge by the target time.

Table 42 – Steps to enable Coordinated Charge/Discharge Mode Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set priority of this mode Optional Direct Operate / Response AO AO102 AI163 2. Set enabling time window Optional Direct Operate / Response AO AO103 AI164 3. Set enabling ramp time Optional Direct Operate / Response AO AO104 AI165 4. Set enabling reversion timeout Optional Direct Operate / Response AO AO105 AI166 Set the Target State of 5. Charge, as a percentage of Required Direct Operate / Response AO AO106 AI167 Usable Capacity Set the Target Date Charge 6. Needed Required Direct Operate / Response AO AO107 AI168 (days since Jan 1, 1970) Set the Target Time Charge 7. Needed (milliseconds since Required Direct Operate / Response AO AO108 AI169 midnight)

Enable coordinated Select / Response, 8. charge/discharge mode and Required BO BO18 BI71 receive response Operate / Response

2.6.4 Active Power Response Modes This profile specifies three identical groups of points that can each be used to control the operation of any of three different modes. In all of these modes, the DER adjusts the active power it generates or absorbs in response to an input active power measurement (i.e. these are “Watt-Watt” modes). This “Reference

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Power Input” may be measured by the System Meter, but is more likely to be measured by an external Signal Meter as described in 2.1.1 and 2.4.2. Table 43 describes the steps and points used to enable any one of these modes. The master may read the value of the Reference Power Input from AI181, AI192, or AI203 respectively. The master may read the attempted output power from AI186, AI197 or AI208 respectively. Table 43 – Steps to enable Active Response Modes using the DNP3 DER Profile Data Point Read-Back Step Description Optionality Function Codes Type Numbers Points AO115, AI176, 1. Set the priority of the mode Optional Direct Operate / Response AO AO124, AI187, AO133 AI198 AO116, AI177, 2. Set enabling time window Optional Direct Operate / Response AO AO125, AI188, AO134 AI199 AO117, AI178, 3. Set enabling ramp time Optional Direct Operate / Response AO AO126, AI189, AO135 AI200 AO118, AI179, 4. Set reversion timeout Optional Direct Operate / Response AO AO127, AI190, AO136 AI201 Identify the meter used to AO119, AI180, measure the Reference 5. Optional Direct Operate / Response AO AO128, AI191, Power Input. By default this AO137 AI202 is the System Meter (ID = 0) AO120, AI182, Set the power threshold for 6. Required Direct Operate / Response AO AO129, AI193, activating the mode AO138 AI204 Set the ratio used to calculate AO121, AI183, 7. the output power from the Required Direct Operate / Response AO AO130, AI194, measured power AO139 AI205 AO122, AI184, Set the maximum ramp up 8. Optional Direct Operate / Response AO AO131, AI195, rate AO140 AI206 AO123, AI185, Set the maximum ramp down 9. Optional Direct Operate / Response AO AO132, AI196, rate AO141 AI207 BO20, BI72, Enable the active response Select / Response, 10. Required BO BO21, BI73, mode Operate / Response BO22 BI74 2.6.4.1 Active Power Response Mode Configured for Peak Power Limiting In Peak Power Limiting mode the DER supplies active power such that the power transferred at a particular reference point does not exceed a specified limit. This concept is illustrated in Figure 22.

Figure 22 – Peak Power Limiting Function Page 212 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

The Reference Power Input for Peak Power Limiting may be located at the same site as the outstation or at another site. The assumption of this function is that increasing the active power output of the outstation will reduce the power transferred at the point of reference, and implementers must ensure this polarity. When this function is enabled, the outstation shall continuously compare the Reference Power Input to a specified Peak Power Limit (the Power Threshold for the mode) and adjust its active power output as needed to ensure the Reference Power Input does not exceed the limit. This function somewhat resembles the Load Following mode described in section 2.6.4.2 in that they both supply active power when the reference power measurement exceeds a threshold. However, they differ in the following fundamental manner: the Load Following function supplies active power in a specified ratio to the power transferred at the reference point, while the Peak Power Limiting function supplies as much active power as necessary (within the physical limits of the outstation) to ensure the measured reference does not exceed the threshold. IMPORTANT: The difference between configuring Peak Limiting Mode and either of the Load Following or Generation Following Modes is that in Peak Limiting Mode, the complete input/output active power of the DER is included in the measured Reference Power Input. This is always the case if the Signal Meter ID is 0, indicating the Reference Power Input is the System Meter. If the Signal Meter ID is non-zero, then to implement Peak Power Limiting mode the Signal Meter ID must identify a meter in which the AI “DER Input/Output Included” (for example, is set to “<2> metered value includes all the input/output of the DER”.

2.6.4.2 Active Power Response Mode Configured for Load Following or Generation Following In Load Following or Generation Following Mode, the DER produces active power in proportion to a measured load (as illustrated in Figure 23), or absorbs active power (charges storage) in proportion to a measured generation source (as illustrated in Figure 24).

Figure 23 – Load Following Function Arrangement and Waveform

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Figure 24 – Generation Following Function Arrangement and Waveform

The Reference Power Input may be located at the same site as the outstation or at another site. It is shown as “M1” in the figures. The assumption regarding this reference is that: • a positive value represents a load and the DER should produce active power to support the load • a negative value represents generation and the DER should absorb excess active power The Load/Generation Following mode will not take action unless the reference value exceeds the Threshold – either a larger positive value if the threshold is positive or a larger negative value if the threshold is negative. The function will generate or absorb active power in proportion to the Reference Power Input based on a specified ratio, as follows: Additional Reference Power Input – Starting Threshold Output Active = x Ratio Power 100 %

This active power will be in addition to the active power generated by any other functions active on the outstation.

2.6.5 Automatic Generation Control Mode – NEW The steps in Table 45 describe how to perform the mode known in some specific jurisdictions as Automatic Generation Control (AGC) mode. In AGC mode, the following rules apply: 1. The master periodically sends an update to an Active Power Target (AO146), expressed in Watts (rather than a percentage of Usable Capacity). A typical period is 4 seconds. The DER does not check whether the master actually achieves this period. The target may be negative or positive, i.e. charging or discharging active power. 2. The DER applies either Ramp Rates or Time Constants to constrain how quickly the DER may adjust the output power to meet the target, as specified in Table 44. 3. The DER also applies Minimum Usable State of Charge (AO153) and Maximum Usable State of Charge (AO154) limits that are unique to this mode and distinct from the DER limits described in 2.6.2. 4. The master may read the Maximum Watts Available (AI222) or Minimum Watts Available (AI223) from the at any time to determine the present capabilities of the DER. 5. The DER updates a prediction for the Expected State of Charge (AI224, Percent) and Expected State of Energy (AI225, Watt-hrs) of the DER. These values are a prediction of the expected state of the DER if the current Active Power Target (AO146) does not change within a specified Page 214 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

length of time (AI226). For example, the DER may report the current state of charge is 75% but it may also indicates using this set of points that the SOC will be 50% in six hours (3600 sec) if the master does not change the Active Power Target before then.

Table 44 – Use of Ramp Rates or Time Constants to Constrain AGC Mode Setting of AGC Mode – Use Charging Discharging Ramp Rates (BO39) Point Name Num Point Name Num AO151, AO149, AGC Charge Ramp Up Rate AGC Discharge Ramp Up Rate <1> Ramp rates should be used AI218 AI216 AGC Charge Ramp Down AO152, AGC Discharge Ramp Down AO150, Rate AI219 Rate AI217 AGC Ramp Time Constant Up AO147, AGC Ramp Time Constant Up AO147, Time AI214 Time AI214 <0> Ramp times should be used AGC Ramp Time Constant AO148, AGC Ramp Time Constant AO148, Down Time AI215 Down Time AI215

Table 45 – Steps to perform Automatic Generation Control (AGC) using the DNP3 DER Profile Read- Data Point Step Description Optionality Function Codes back Type Number Point 1. Set priority of the mode Optional Direct Operate / Response AO AO142 AI209 2. Set enabling time window Optional Direct Operate / Response AO AO143 AI210 3. Set enabling ramp time Optional Direct Operate / Response AO AO144 AI211 4. Set enabling reversion timeout Optional Direct Operate / Response AO AO145 AI212 Select whether to use Ramp Rates 5. Optional Direct Operate / Response BO BO39 BI91 or Time Constants Set the Ramp Rates or Time See See 6. Optional Direct Operate / Response AO Constants Table 44 Table 44 Set Minimum Usable State of 7. Charge (percent of Usable Optional Direct Operate / Response AO AO153 AI220 Capacity Rating) Set Maximum Usable State of 8. Charge (percent of Usable Optional Direct Operate / Response AO AO154 AI221 Capacity Rating) Set the Active Power Target (in 9. Watts) Positive is discharging, Required Direct Operate / Response AO AO146 AI213 negative is charging. Enable AGC mode and receive Select / Response, 10. Required BO BO23 BI75 response. Operate / Response Once the mode is enabled, 11. periodically update the Active Required Direct Operate / Response AO AO146 AI213 Power Target. Read the predicted State of 12. Optional Read AI n/a AI224 Charge

2.6.6 Active Power Smoothing The steps in Table 46 describe how to request that the DER absorb or produce additional Watts in such a way as to smooth-out variations in the power level of a remote point of reference. It is assumed that if a device supports this function, it has a dedicated “remote reference meter” input of some kind, as illustrated by location M2 in Figure 25. The Reference Power Input for Real Power

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Smoothing (AO159) may be representative of a load or generation source or both. It is out of the scope of this document what the source is, where it is located, or how the measurement is gathered by the outstation.

Figure 25 – Possible Measurement Points

This function operates by computing the instantaneous difference in the reference meter power level and a moving average of the power level over a sliding time window. In this way, the system helps to “smooth” the power waveform at the reference point. This function utilizes the similar basic concepts and settings as the Dynamic Reactive Current function described in 2.5.3 but uses active power rather than voltage or current as both input and output. This function identifies “additional Watts”, not absolute Watts, so that it is compatible with other Watt- managing functions, such as scheduled battery system charging and discharging. For example, a battery system that is being charged and discharged daily for arbitrage purposes may, by this function, modulate its charging and discharging levels moment by moment to compensate for variability in some other nearby load or generation resource. Figure 26 illustrates how the outstation shall calculate a moving average of the Reference Power Measurement over a specified number of seconds known as the Filter Time (AO163).

W Average over FilterTms

Delta Wattage at Present

Load Load or Generation FilterTms Wattage of Reference of Reference Wattage

Time Present

Figure 26 – Delta Wattage Calculation

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The difference beween this Moving Average Power and the Measured Reference Power at any moment is defined to be the Delta Wattage, as follows:

Delta Wattage = Measured Reference Power (AI232) – Moving Average Power

Neither the Delta Wattage or the Moving Average Power is available at the outstation for reading by the master. Figure 27 illustrates how the outstation generates or absorbs active power in proportion to the Delta Wattage at any moment, in addition to any active power produced or absorbed by other functions.

DbWLo DbWHi Deadband Smoothing Gradient Delta Wattage (Present Wattage Minus Moving Average)

Moving Additional Watts Additional Smoothing Average of Gradient Reference Power

Figure 27 – Active Power Smoothing Mode

The master specifies the curve in Figure 27 using three values. Firstly, it specifies two Wattage thresholds that define a “deadband”. When the Delta Wattage is above the Real Power Smoothing Lower Limit (AO161) and below the Real Power Smoothing Upper Limit (AO162) the outstation shall not perform real power smoothing. Secondly, the master specifies a unit-less gradient, defined as follows:

Real Power Smoothing Additional Watts Produced = Gradient (AO160) Delta Wattage

Unlike the Dynamic Reactive Current function, the outstation applies the same gradient regardless of whether the Delta Wattage is positive or negative. The Active Power Smoothing Gradient is a signed quantity. Positive values of this gradient are for following load (increasing reference load results in a dynamic increase in DER output), and negative values are for following generation (increasing reference generation results in a dynamic decrease in DER output). Table 46 – Steps to enable Active Power Smoothing using the DNP3 DER Profile

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Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set priority of this mode Optional Direct Operate / Response AO AO155 AI227 2. Set time window Optional Direct Operate / Response AO AO156 AI228 3. Set ramp time Optional Direct Operate / Response AO AO157 AI229 4. Set reversion timeout Optional Direct Operate / Response AO AO158 AI230 Identify the meter used to measure the 5. Reference Power Input. Optional Direct Operate / Response AO AO159 AI231 By default this is the System Meter (ID = 0) Set the Active Power 6. Optional Direct Operate / Response AO AO160 AI233 Smoothing Gradient Set the Active Power 7. Optional Direct Operate / Response AO AO161 AI234 Smoothing Lower Limit Set the Active Power 8. Optional Direct Operate / Response AO AO162 AI235 Smoothing Upper Limit Set the Active Power 9. Optional Direct Operate / Response AO AO163 AI236 Smoothing Filter Time Set the Discharge Ramp 10. Optional Direct Operate / Response AO AO164 AI237 Up Rate Set the Discharge Ramp 11. Optional Direct Operate / Response AO AO165 AI238 Down Rate Set the Charge Ramp 12. Optional Direct Operate / Response AO AO166 AI239 Up Rate Set the Charge Ramp 13. Optional Direct Operate / Response AO AO167 AI240 Down Rate Enable Active Power Select / Response, 14. Required BO BO24 BI76 Smoothing Mode Operate / Response

2.6.7 Volt-Watt Mode The steps in Table 47 describe how to cause the photovoltaic generation and storage system to alter its active power output based on measured voltage (usually the local voltage). The master defines the curve relating voltage to output Watts using the generic curve data points (AO244 through AO448 )The concept of using generic curves is described in section 2.3.3. A typical curve for avoiding unintentional high voltage or low voltage on a feeder is illustrated in Figure 28. The DER maintains its active power within the area bounded by the curve. This curve cannot be defined with hysteresis.

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P1 WMax: Max Generating Power P2

Zone 2: Generating, Zone 1: Generating, Low Voltage High Voltage P2-P3 gradient, = HiWGra = % of WMax per 1% of

Active Power Output nominal voltage

(Generating) or g

n Input (Consuming) i t

a P1-P6 gradient, r

e or LoWGra n e G

–

r e w

o P6 P3 P

e v i t System Voltage c A

- Nominal P3-P4 gradient, or g Voltage n HiWChaGra i P5-P6

m Zone 4: Consuming,

u gradient, or

s Low Voltage

n LoWChaGra o

C Zone 3: Consuming,

High Voltage

P5 P4 WChaMax: Max Consuming Power Figure 28 – Example Volt-Watt Curve

The X-Values of the curve points shall be a percentage of nominal voltage, calculated as follows:

Percent Voltage Voltage at the Curve Point = x 100 % (X-Value of Curve) Nominal Voltage

Where the outstation shall calculate the nominal voltage as follows when executing the curve:

Nominal Voltage = Reference Voltage (AO0) + Reference Voltage Offset (AO1)

This active power is a signed value. If it is negative, it indicates that the system shall charge storage rather than producing power for the given voltage. The Y-values of the curve points shall be calculated as follows if the DER is discharging / generating:

Percent Active Output Active Power (AI537) Power Output = x 100 % (Y-Value) Maximum Active Discharging Power (AI32)

The Y-values of the curve points shall be calculated as follows if the DER is charging:

Percent Active Output Active Power (AI537) Power Output = x 100 % (Y-Value) Maximum Active Charging Power (AI33)

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Table 47 – Steps to enable a Volt-Watt curve using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set priority of this mode Optional Direct Operate / Response AO AO168 AI242

2. Set time window Optional Direct Operate / Response AO AO169 AI243

3. Set ramp time Optional Direct Operate / Response AO AO170 AI244

4. Set reversion timeout Optional Direct Operate / Response AO AO171 AI245 Identify the meter used to 5. measure the Voltage. By default Optional Direct Operate / Response AO AO172 AI246 this is the System Meter (ID = 0) Set the reference voltage if it has 6. Optional Direct Operate / Response AO AO0 AI29 not already been set Set the reference voltage offset if 7. Optional Direct Operate / Response AO AO1 AI30 it has not already been set 8. Select which curve to edit Required Direct Operate / Response AO AO244 AI328 Specify the Curve Mode Type as 9. Optional Direct Operate / Response AO AO245 AI329 <5> Volt-Watt Mode Specify that the Independent (X- 10. Value) units are <129> Percent Optional Direct Operate / Response AO AO247 AI331 Voltage Specify the Dependent (Y-Value) 11. units are <5> Watts as a Optional Direct Operate / Response AO AO248 AI332 Percentage of Max Watts Set time (X-Values) for each AO249, curve point to the voltage as a AI333, 12. Optional Direct Operate / Response AO AO251 percentage of the reference AI335 … … voltage Set active power (Y-Values) for AO250, each curve point to the active AI334, 13. Optional Direct Operate / Response AO AO252 power as a percentage of AI336 … … maximum active power Set number of points used for the 14. Optional Direct Operate / Response AO AO246 AI330 curve. Identify the index of the curve 15. Optional Direct Operate / Response AO AO173 AI248 being used Select / Response, 16. Enable the Volt-Watt Mode Required BO BO25 BI77 Operate / Response Read the maximum active power Class the outstation will attempt to 17. Optional Read 0,1, 2 n/a AI249 generate or absorb based on the OR 3 voltage and the curve in use. Class Read the actual active power 18. Optional Read 0,1, 2 n/a AI537 produced or absorbed OR 3

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2.6.8 Frequency-Watt Curve Mode The steps in Table 48 describe how to cause the DER to alter its active power output in response to the measured deviation from a specified nominal frequency. This mode is very similar to that described in 2.5.3 except it uses curves rather than individual parameters to specify the behavior. Refer to that section for details of the expected behavior. In this mode, the master defines the curve relating frequency to Watts using the generic curve data points (AO244 through AO448).The concept of using generic curves is described in section 2.3.3. A typical Frequency-Watt curve is illustrated in Figure 29. In this profile, there will always be six points.

Figure 29 – Basic Frequency-Watt Curve

In this mode, some of the parameters discussed in 2.5.3 are identified in the curve itself, as follows: • The X-value of the second point (P2 in the figure) represents the starting frequency for over- frequency events, named HiHzStr in IEC 61850. • The X-value of the sixth point (P6) represents the starting frequency for under-frequency events, LoHzStr. • The gradients used are determined by subtracting the X-values and Y-values of pairs of points on the Frequency-Watt curve. For instance, the High Frequency Discharging / Generating Gradient is calculated from the rise divided by the run of the line between P3 and P2. The X-value of each point on the curve is defined as: Frequency Deviation = Signal Meter Frequency – Nominal Frequency (AO2) (X-Value)

The Y-value of each point on the curve is the percentage of active power (Watts) to be provided at the given amount of deviation from nominal frequency. The Y-values of the curve points shall be calculated as follows if the DER is discharging / generating: Page 221 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

Percent Active Output Active Power (AI537) Power Output = x 100 % (Y-Value) Maximum Active Discharging Power (AI32)

The Y-values of the curve points shall be calculated as follows if the DER is charging:

Percent Active Output Active Power (AI537) Power Output = x 100 % (Y-Value) Maximum Active Charging Power (AI33)

The master may enable hysteresis in Frequency-Watt mode using BO36. The boundaries of hysteresis shall be defined by two more curves, one for use in high-frequency events, the other for low-frequency events. An example of a hysteresis curve for high-frequency events is illustrated in Figure 30. Note that the High Stopping Frequency parameter (HiHzStop) is defined by point H6. For this reason, Frequency- Watt Curve Mode always requires both hysteresis curves to be defined, even if hysteresis is not enabled.

Figure 30 – Frequency-Watt Curve with Hysteresis

If the master disables Snapshot of Power (BO37), the DER will not necessarily begin altering its active power output when the HiHzStr or LoHzStr limits are exceeded. It will maintain its output within the blue area bounded by P1 through P6 in Figure 29, but will not follow the dashed red line. Instead, its behavior may be similar to that shown for Volt-Watt mode in Figure 28 on page 219.

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Table 48 – Steps to enable a Frequency-Watt curve using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set priority of this mode Optional Direct Operate / Response AO AO181 AI257

2. Set time window Optional Direct Operate / Response AO AO182 AI258

1. Set ramp time Optional Direct Operate / Response AO AO184 AI259

2. Set reversion timeout Optional Direct Operate / Response AO AO183 AI260 Identify the meter used to measure the Frequency. By 3. Optional Direct Operate / Response AO AO185 AI261 default this is the System Meter (ID = 0) Set the Nominal Grid Frequency if 4. Optional Direct Operate / Response AO AO2 AI31 it is not already set 5. Select which curve to edit Required Direct Operate / Response AO AO244 AI328 Specify the Curve Mode Type as 6. Optional Direct Operate / Response AO AO245 AI329 <3> Frequency-Watt mode Specify that the Independent (X- 7. Value) units are <133> Percent Optional Direct Operate / Response AO AO247 AI331 Frequency Specify the Dependent (Y-Value) 8. units are <5> Watts as a Optional Direct Operate / Response AO AO248 AI332 Percentage of Max Watts AO249, AI333, Set percent frequency (X-Values) 9. Optional Direct Operate / Response AO AO251 AI335 for each curve point … … AO250, AI334, Set percent active power (Y- 10. Optional Direct Operate / Response AO AO252 AI336 Values) for each curve point … … Set the starting and stopping AO189, AI266, 11. Optional Direct Operate / Response AO delays AO190 AI267 Set the time constants for the AO191, AI268, 12. Optional Direct Operate / Response AO output of the curve AO192 AI269 AO193, AI270, AO194, AI271, 13. Set the ramp rates for the curve Optional Direct Operate / Response AO AO195, AI272, AO196 AI273 Set number of points used for the 14. Optional Direct Operate / Response AO AO246 AI330 curve. Identify the index of the main AO186, AI263, 15. curve and the two hysteresis Optional Direct Operate / Response AO AO187, AI264, curves being used AO188 AI265 Set the minimum and maximum AO197, AI275, 16. state of charge in which this Optional Direct Operate / Response AO AO198 AI276 mode shall operate 17. Choose whether to use hysteresis Optional Direct Operate / Response BO BO36 BI88 Choose whether to snapshot 18. Optional Direct Operate / Response BO BO37 BI89 power Enable the Frequency-Watt Select / Response, 19. Required BO BO26 BI78 Curve Mode Operate / Response

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2.7 Reactive Power Modes The modes described in this section control the reactive power (VArs) output of the DER in “non- emergency” situations.

2.7.1 Constant VArs Mode – NEW The steps in Table 50 describe how to cause the DER to produce a fixed amount of VArs. The outstation shall start the time window, reversion timeout, and ramp time at the moment the master successfully operates the mode enable command. The master may set the Constant VArs Reactive Power Target as a percentage of either the maximum reactive power, or the available reactive power, according to the value of AO5, and whether the target is positive or negative, as illustrated in Table 49. This value also selects which type of generation should take precedence, i.e. Watts or VArs. The priority of the Constant VArs mode compared to other modes shall override this selection, i.e. if an active power mode has a higher priority than Constant VArs mode, producing Watts shall have precedence. Table 49 – Choices for the meaning of the Constant VArs Reactive Power Target Seting of Reference Sign of Reactive Action Name of Reference Precedence of Point for Reactive Power Power Target Taken by Reactive Power Generation Number Setpoints (AO5) (AO203) DER (representing 100%) Maximum Active <1> Percent of Positive Inject VArs AI32 Maximum Active Not supported in this Generation Power Power profile Maximum Active Negative Absorb VArs AI33 (DRCT.WMax) Charging Power VARs before Watts. Maximum Reactive The DER produces Positive Inject VArs AI34 <2> Percent of the specified Injection Power Maximum percentage of its Reactive Power maximum reactive (DRCT.VArMax) power output Maximum Reactive Negative Absorb VArs AI35 regardless of its Absorption Power active power output. Watts before VArs. System Available <3> Percent of The DER produces Positive Inject VArs Reactive Injection AI45 Available the requested Power Reactive Power percentage of the (DINV.VArAvl) VArs available, given System Available (default) its current active Negative Absorb VArs Reactive Absorption AI46 power (Watt) output. Power

Reactive Power Desired Reactive Power = x 100 % Target (AO203) Reference Reactive Power (see Table 49)

Note that this function and the Volt/VAr Control mode and Fixed Power Factor Mode are mutually exclusive, it only being possible for one mode to be in effect at any time. Refer to 2.10.4 for details.

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Table 50 – Steps to set Constant VAr output using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set the priority of this mode Optional Direct Operate / Response AO AO199 AI277 2. Set enabling time window Optional Direct Operate / Response AO AO200 AI278 3. Set enabling ramp time Optional Direct Operate / Response AO AO201 AI279 4. Set enabling reversion timeout Optional Direct Operate / Response AO AO202 AI280 AO204, AI282, 5. Set the Time Constants Optional Direct Operate / Response AO AO205 AI283 Choose whether the time constants represent 3-Tau 6. Optional Direct Operate / Response BO BO9 BI28 limits or Open Loop Response Times If Open Loop Response Times are selected, choose the 7. percentage of final output Optional Direct Operate / Response AO AO3 AI40 represented by the time constant (e.g. 90% or 95%) Select the meaning of the AO5; See 8. Constant VArs Reactive Power Optional Direct Operate / Response AO Table 49 AI42 Target for values Read the appropriate limit that Read / Response OR See 9. will represent 100% reactive Optional AI n/a Table 49 power Unsolicited Response Set the Constant VArs 10. Reactive Power Target in Required Direct Operate / Response AO AO203 AI281 percent Enable Constant VArs mode Select / Response, 11. Required BO BO27 BI79 and receive response Operate / Response

2.7.2 Fixed Power Factor Mode The steps in Table 52 describe how to set the power factor produced by the DER. The outstation shall start the time window, reversion timeout, and ramp time at the moment the master successfully operates the mode enable command. Note that this function and the Volt/VAr or Constant VAr modes are mutually exclusive, i.e. it is only possible for one or the other to be in effect at any time. Refer to 2.10.4 for details. Power factor, when measured, is a signed value between -1.00 and +1.00. Both -1.00 and +1.00 produce the same result, no VARs. A PF setting of Zero is not allowed. In the power industry, the meaning of the sign of the value varies depending on the sign convention used, shown in Figure 31: • IEC, in which supplying or generating active power is positive and demanding active power is negative • IEEE (or EEI), in which a leading (capacitive) power factor is positive and a lagging (inductive) power factor is negative This profile uses only the IEC convention. IEC 61850 defines the data attribute PFSign which is implemented in this profile as AO4, but devices implementing this profile shall respond with a PARAMETER ERRROR indication if the master attempts to change its value. IEC 61850 also defines two parameters called Power Factor Excitation (PFExt) to force whether the system must inject VARs or absorb VARs when charging or discharging/generating active power. This

Page 225 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs) profile makes these parameters visible in BO10 and BO11. As illustrated in Table 51, the combination of whether the DER is charging or discharging plus the value of the appropriate PFExt determines which quadrant the DER is operating in. This in turn determines what the sign of the power factor and the excitation will be when read by the master. The value of power factor setpoint written by the master is unsigned. There is a different setpoint used when generating / discharging or when charging, as listed in Table 51. Table 51 – Parameters and Behavior when setting a Fixed Power Factor Active Power Factor Power Measured Measured Power Excitation Value of PFExt Resulting Factor Power VArs (PFExt) Point Point Quadrant Setpoint Factor (AI537) Used Used (AI545) (AI544) Generating / <0>Injecting Discharging BO10 Q1 AO210 + + VArs (+) Generating / <1> Asorbing Discharging BO10 Q4 AO210 + − VArs (+) Charging <0> Injecting BO11 Q2 AO211 − + (-) VArs Charging <1> Absorbing BO11 Q3 AO211 − − (-) VArs

Figure 31 – Power Factor Sign Conventions

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Table 52 – Steps to set a Fixed Power Factor using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set the priority of this mode Optional Direct Operate / Response AO AO206 AI284 2. Set enabling time window Optional Direct Operate / Response AO AO207 AI285 3. Set enabling ramp time Optional Direct Operate / Response AO AO208 AI286 4. Set enabling reversion timeout Optional Direct Operate / Response AO AO209 AI287 Set the requirement for whether to inject or absorb 5. Optional Direct Operate / Response BO BO10 BI29 VARs (PFExt) when discharging / generating Set the requirement for whether to inject or absorb 6. Optional Direct Operate / Response BO BO11 BI30 VARs (PFExt) when discharging / generating Set Fixed Power Factor 7. Setpoint to use when Required Direct Operate / Response AO AO210 AI288 generating / discharging Set Fixed Power Factor 8. Required Direct Operate / Response AO AO211 AI289 Setpoint to use when charging Enable fixed power factor Select / Response, 9. Required BO BO28 BI47 mode and receive response Operate / Response

2.7.3 Volt-VAr Control Mode This section describes how to cause the DER to produce or absorb reactive power (VArs) as a function of the locally-observed voltage. This function makes use of the concept of generic curves as described in section 2.3.3. The desired Volt-VAr behavior is defined by a piece-wise linear curve of up to 100 curve points, each of which is specified by a percent Voltage (X-Value) and a percent VAr (Y-Value). This generic curve definition is also used for a variety of other functions, such as Frequency-Watt, Watt- Power Factor, Volt-Watt, etc. More than one curve may be in use by the DER at a time, for example, a Volt-VAR curve and a Volt-Watt curve may both be active. The maximum number of Volt/VAr curves is therefore only limited by the resources available on the outstation. Outstations shall be pre-configured so all curves produce zero VArs at all voltages.

2.7.3.1 Precedence of Generation In general, the preconfigured priority of modes shall establish the precedence of generation, i.e. whether the DER gives priority to producing VArs or Watts. If an active power mode such as Peak Power Limiting is given a higher priority (lower priority number) than Volt-VAr Control, Watts shall not be curtailed in order to produce VArs, and Volt-VAr Control Mode shall use the available VAr capacity after Peak Power Limiting has commanded Watts. However, in some cases there is no mode directly associated with active power generation, e.g. in the case of a photovoltaic system. In that case, the Y-Value Units of the Volt-VAr curve shall specify the priority of VArs over Watts or vice versa, as shown in Table 53. The Y-Value Units shall also specify the Reactive Power Reference Input that is used to calculate the output VArs.

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Table 53 – Choice of Reference Reactive Power Setting of the Y- Sign of Reactive Action Reference Reactive Precedence of Point Value Units for Power Target Taken by Power Generation Number Curve (e.g. AO248) (Y-Value) DER (representing 100%) VARs before Watts. Maximum Reactive The DER produces Positive Inject VArs AI34 the specified Injection Power <2> VArs as a percentage of its percent of Max maximum reactive VArs (VArMax) power output Maximum Reactive Negative Absorb VArs AI35 regardless of its Absorption Power active power output. Watts before VArs. System Available The DER produces <3> VArs as a Positive Inject VArs Reactive Injection AI45 the requested percent of max Power percentage of the available VArs VArs available, given System Available (VArAval) its current active Negative Absorb VArs Reactive Absorption AI46 power (Watt) output. Power Maximum Active <4> Vars as a Positive Inject VArs AI32 Not supported in this Generation Power percent of max profile Maximum Active Watts Negative Absorb VArs AI33 Charging Power

2.7.3.2 Defining Hysteresis This profile permits each Volt/VAR curve to be set in such a way that hysteresis can be specified, i.e. a different curve is to be used depending on whether voltage is increasing or decreasing. To do so, the master shall follow the following rules: 1. The Voltage (X-values) of each curve must initially always increase, up to a Maximum Voltage value for that curve. In Figure 32, the Maximum Voltage is shown as P4.

P1 P2

P7 P6

Percent Voltage % Available VARs % Available Voltage Rising P3 P4 Voltage Falling P5

100%

Figure 32 – Volt/VAR Curve with Hysteresis

1. If the curve used by the outstation is to be different when Voltage is decreasing, the Voltage (X- Value) of the next point and all subsequent points after the Maximum Voltage point must always decrease (e.g. P5, P6 and P7) 2. If the curve used by the outstation is to be the same regardless of whether the voltage is increasing or decreasing, the curve shall end at the Maximum Voltage point. Figure 33 illustrates this type of curve.

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Q1 P1 V3 V1 0%

Capacitive P2 Percent Voltage

P3 V4 % Available VARs Available % V2 100% Inductive P4 Q4

Figure 33 – Volt/VAR Curve without Hysteresis 2.7.3.3 Interpreting the Curve When operating in a Volt/VAr Control mode, the outstation shall implement the following rules: 1. If the locally measured voltage is increasing, the outstation shall use the points of the curve that were specified BEFORE the Maximum Voltage point and including that point. 2. If the locally measured voltage is decreasing and there are points defined after the Maximum Voltage point, the outstation shall use the points of the curve that were specified by the master AFTER the Maximum Voltage point and including that point. 3. When the direction of the voltage changes (moving between the curves) or the voltage is beyond the ends of the curves, either increasing or decreasing, the outstation shall keep VARs constant, as shown by the horizontal arrows in Figure 32, until the appropriate curve is reached. 4. If there were no points specified after the Maximum Voltage point, the outstation shall use the same points regardless of whether the locally measured voltage is increasing or decreasing, as shown in Figure 33. 5. The X-Values of the curve points shall be defined as a percentage of the nominal voltage at the outstation, as follow:

Percent Voltage Voltage at the Curve Point = x 100 % (X-Value of Curve) Nominal Voltage

When executing the curve, the outstation shall calculate the nominal voltage as:

Nominal Voltage = Reference Voltage (AO0) + Reference Voltage Offset (AO1)

This calculation permits the master to write the same Percent Voltage values to many different outstations without adjusting for local conditions at each outstation. Such adjustments can be made by setting the Reference Voltage or Reference Voltage Offset when the device is first commissioned and occasionally after, without affecting the curve settings. 6. The requested VAr (Y-Value) to be written for each curve point shall be a percentage to be calculated as follows:

Percent VARs Desired Reactive Power = x 100 % (Y-Value of Curve) Reference Reactive Power (see Table 53)

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The percentage of VArs is a signed value, so that it can represent VArs injected (positive) or absorbed (negative). 7. The source of the locally measured voltage may vary by outstation. It may be one of the phase- to-ground voltages, an average of these voltages, or some other measurement. It may be measured by the System Meter or some other meter, as discussed in 2.1.1 and 2.4.2.

2.7.3.4 Autonomously Adjusting the Voltage Reference – NEW Instead of using the fixed Voltage Reference (AO0 and AO1), the master may direct the DER to autonomously adjust the Voltage Reference as described in the following text from IEEE Std 1547:

The DER shall be capable of autonomously adjusting reference voltage (VRef) with VRef being equal to the low-pass filtered measured voltage. The time constant shall be adjustable at least over the range of 300 s to 5000 s. The voltage-reactive power Volt-Var curve characteristic shall be adjusted autonomously as VRef changes. The master may enable autonomous adjustment of the reference voltage by setting BO41 to 1/TRUE/Enabled. This will cause the DER to calculate the reference voltage for Volt-VAr control by passing the measured voltage through a low-pass filter with the time constant specified in AO220. Note that this value is always a Time Constant and never the Open Loop Response Time discussed in 2.3.4. The master may read the value of the calculated reference voltage in AI296. If BO41 is set to 0/FALSE/Disabled, then AI296 will equal AO0.

2.7.3.5 Creating a Volt/VAR Curve using the Generic Curve Points The process is outlined in Table 54. The concept of using generic curves is described in section 2.3.3. The steps to define the type of curve, and to edit the shape of the curve and the timeout parameters are optional if they have already been performed once, or if the desired curve was pre-defined in the configuration of the outstation. Table 54 – Steps to change and select a Volt/VAR curve Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set priority of this mode Optional Direct Operate / Response AO AO212 AI290

2. Set the enabling time window Optional Direct Operate / Response AO AO213 AI291

3. Set the enabling ramp time Optional Direct Operate / Response AO AO214 AI292 Set the enabling reversion 4. Optional Direct Operate / Response AO AO215 AI293 timeout Identify the meter used to 5. measure the voltage. By default Optional Direct Operate / Response AO AO216 AI294 this is the System Meter (ID = 0) If using a fixed Voltage reference: 6. Optional Direct Operate / Response AO AO0 AI29 Set the reference voltage if it has not already been set If using a fixed Voltage reference: 7. Set the reference voltage Optional Direct Operate / Response AO AO1 AI30 offset if it has not already been set If autonomously adjusting the Voltage reference: 8. Optional Direct Operate / Response AO AO220 AI300 Set the time constant for the lowpass filter

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Data Point Read-back Step Description Optionality Function Codes Type Number Point If autonomously adjusting the Voltage reference: 9. Optional Direct Operate / Response BO BO41 BI93 Enable autonomous adjustment 10. Select which curve to edit Optional Direct Operate / Response AO AO244 AI328 Specify the Curve Mode Type as 11. Optional Direct Operate / Response AO AO245 AI329 <2> Volt-VAr mode Specify that the Independent (X- 12. Value) units are <129> Percent Optional Direct Operate / Response AO AO247 AI331 Voltage Specify the Dependent (Y-Value) 13. Optional Direct Operate / Response AO AO248 AI332 units as described in Table 53. AO249, AI333, Set percent voltage (X-Values) 14. Optional Direct Operate / Response AO AO251 AI335 for each curve point … … AO250, AI334, Set percent VArs (Y-Values) for 15. Optional Direct Operate / Response AO AO252 AI336 each curve point … … Set number of points used for 16. Optional Direct Operate / Response AO AO246 AI330 the curve. Set the time constant for the AO218, AI298, 17. Optional Direct Operate / Response AO output of the curve AO219 AI299 Identify the index of the curve 18. Optional Direct Operate / Response AO AO217 AI297 being used Enable the Volt-VAr Control Select / Response, 19. Required BO BO29 BI48 Mode Operate / Response Read the adjusted reference Class 20. Optional Read n/a AI296 voltage, if it is not fixed 1/2/3 Class 21. Read the measured Voltage Optional Read n/a AI295 1/2/3 Class 22. Read the attempted VArs Optional Read n/a AI301 1/2/3 Read the actual VArs (if using Class 23. Optional Read n/a AI541 system meter) 1/2/3

2.7.4 Watt-VAr Power Mode – NEW The steps in Table 55 describe how to cause the DER to inject or absorb reactive power (VArs) in response to the active power (Watts) measured by a specified meter. The use of generic curves is described in 2.3.3 and the process of creating the curve is similar to that described in 2.7.3 with different X-axis units. The X-Values of the curve are calculated as follows when discharging:

Percent Active Measured Active Power (AI307) Power Output = x 100 % (X-Value) Maximum Active Generation Power (AI32) T The X-Values of the curve are calculated as follows when charging:

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Percent Active Measured Active Power (AI307) Power Output = x 100 % (X-Value) Maximum Active Charging Power (AI33)

Table 55 - Steps to enable Watt-VAr Power Mode using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point Direct Operate / 1. Set priority of this mode Optional AO AO221 AI302 Response Direct Operate / 2. Set the enabling time window Optional AO AO222 AI303 Response Direct Operate / 3. Set the enabling ramp time Optional AO AO223 AI304 Response Set the enabling reversion Direct Operate / 4. Optional AO AO224 AI305 timeout Response Identify the meter used to measure the active power. By Direct Operate / 5. Optional AO AO225 AI306 default this is the System Meter Response (ID = 0) Read the maximum Watts used Direct Operate / 6. as the reference for percent Optional AI n/a AI32 or AI33 Response Watts Direct Operate / 7. Select which curve to edit Optional AO AO244 AI328 Response Specify the Curve Mode Type Direct Operate / 8. Optional AO AO245 AI329 as <4> Watt-VAr mode Response Specify that the Independent (X- Direct Operate / 9. Value) units are <138> Percent Optional AO AO247 AI331 Response Watts Specify the Dependent (Y- Direct Operate / 10. Value) units as described in Optional AO AO248 AI332 Response Table 53 on page 228. Set percent Watts (X-Values) Direct Operate / AO249, AI333, 11. Optional AO for each curve point Response AO251 … AI335 … Set percent VArs (Y-Values) for Direct Operate / AO250, AI334, 12. Optional AO each curve point Response AO252 … AI336 … Set number of points used for Direct Operate / 13. Optional AO AO246 AI330 the curve. Response Set the time constants for the Direct Operate / AO227, AI309, 14. Optional AO output of the curve Response AO228 AI310 Identify the index of the curve Direct Operate / 15. Optional AO AO226 AI308 being used Response Enable the Watt-VAr Power Select / Response, 16. Required BO BO30 BI49 Mode Operate / Response

2.7.5 Power Factor Correction Mode – NEW The steps in Table 56 describe how to cause the DER attempt to keep the measured power factor on all phases within an upper and lower limit and the average near a specified target. Settings for the interpretation of power factor are described in 2.7.2. In Power Factor Correction mode, the DER reads all three phases at the monitored point and compares them to the specified Upper and Lower Limits (AO236 and AO235). If the monitored power factor of any phase exceeds one of these limits, the DER will not drive the power factor in the direction of that limit.

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The DER also computes an average power factor from the readings of the three phases. If not prevented from doing so by a phase exceeding one of the limits, the DER compares this average to the specified Average PF Target (AO234). It then adjusts the reactive power output of the system to move the monitored power factor closer to this Average Target.

Figure 34 – Power Factor Correction Mode Example Table 56 – Steps to enable Power Factor Correction Mode using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set the priority of this mode Optional Direct Operate / Response AO AO229 AI312 2. Set enabling time window Optional Direct Operate / Response AO AO230 AI313 3. Set enabling ramp time Optional Direct Operate / Response AO AO231 AI314 4. Set enabling reversion timeout Optional Direct Operate / Response AO AO232 AI315 Identify the meter used to measure the active power. By 5. Optional Direct Operate / Response AO AO233 AI316 default this is the System Meter (ID = 0) Set the requirement for whether to inject or absorb BO10, BI29, 6. Optional Direct Operate / Response AO VARs (PFExt) when charging BO11 BI30 or discharging. 7. Set the Average PF Target Required Direct Operate / Response AO AO234 AI317 8. Set the Lower PF Limit Required Direct Operate / Response AO AO235 AI318 9. Set the Upper PF Limit Required Direct Operate / Response AO AO236 AI319 Enable Power Factor Select / Response, 10. Required BO BO31 BI83 Correction Mode Operate / Response

2.8 Pricing Signal Mode The steps in Table 57 describe how to initiate changes in the DER based on a pricing signal. The format of the pricing signal and the behavior of the system after receiving the pricing signal are not specified in detail. In this version of the specification, the pricing signal is simply considered to be an number representing a price per (active) kilowatt-hour in one-hundredths of the local currency. In North America, for example, it would be appropriate for the price value to represent cents of U.S. Dollars, with

Page 233 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs) sufficient resolution to represent hundredths of cents. Utilities must make agreements with suppliers regarding the meaning of the pricing signal within their service area. Table 57 – Steps to signal a price change using the DNP3 DER Profile Data Point Read-back Step Description Optionality Function Codes Type Number Point 1. Set priority of this mode Optional Direct Operate / Response AO AO237 AI321 2. Set enabling time window Optional Direct Operate / Response AO AO238 AI322 3. Set enabling ramp time Optional Direct Operate / Response AO AO239 AI323 Set enabling reversion 4. Optional Direct Operate / Response AO AO240 AI324 timeout Set pricing mode time AO242, AI326, 5. constants for ramping up Optional Direct Operate / Response AO AO243 AI327 and down Set pricing signal and Select / Response, 6. Required AO AO241 AI325 receive response Operate / Response Enable pricing signal mode Select / Response, 7. Required BO BO32 BI84 and receive response Operate / Response

2.9 Scheduling of Modes Many of the modes previously described can be performed according to a schedule. A schedule is a curve in which the X-value is a Time Offset (specified as a number of seconds) from the start of the schedule and the Y-value (Schedule Value) is either: • The set point for one of the core operating modes in the profile, or • A value indicating a mode should be turned on or off using its existing configuration parameters; for instance, applying whichever curve index the master most recently set for that mode. Table 58 shows the way the outstation shall interpret each Schedule Value depending on the Schedule Type set by the master. When a schedule is enabled by the master, the outstation activates each of the Schedule Values when the corresponding Time Offset has elapsed from the configured Start Time.

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Table 58 – Schedule Value Interpretation Based on Schedule Type Equivalent to Setting Schedule Type (AO S + 3) Schedule Value (e.g. AO S+ 10) Point Number <1> Low/High Voltage Ride-Through – Hi Must Trip High Must Trip Curve Index AO23 <2> Low/High Voltage Ride-Through – Low Must Trip Low Must Trip Curve Index AO24 <3> Low/High Voltage Ride-Through – Hi Momentary High Momentary Cessation Curve Index AO25 <4> Low/High Voltage Ride-Through – Lo Momentary Low Momentary Cessation Curve Index AO26 <5> Low/High Frequency Ride-Through – Hi Must Trip High Must Trip Curve Index AO28 <6> Low/High Frequency Ride-Through – Lo Must Trip Low Must Trip Curve Index AO29 <7> Low/High Frequency Ride-Through – Hi Momentary High Momentary Cessation Curve Index AO30 <8> Low/High Frequency Ride-Through – Low Momentary Low Momentary Cessation Curve Index AO31 <9> Dynamic Reactive Current Support - On/Off 1 = ON, 0 = OFF --- <10> Dynamic Volt-Watt - On/Off 1 = ON, 0 = OFF --- <11> Frequency-Watt - On/Off 1 = ON, 0 = OFF --- <12> Active Power Limit - Charging Active Power Limit Charge Setpoint. AO87 <13> Active Power Limit - Generating Active Power Limit Generation Setpoint. AO88 <14> Charge/Discharge - Percent of Maximum Charge/Discharge Active Power Target AO93 Coordinated Charge/Discharge <15> Coordinated Charge/Discharge - SOC Target AO106 Target State of Charge. <16> Active Power Response #1 - On/Off 1 = ON, 0 = OFF --- <17> Active Power Response #2 - On/Off 1 = ON, 0 = OFF --- <18> Active Power Response #3 - On/Off 1 = ON, 0 = OFF --- <19> AGC – Watts AGC Active Power Target AO146 <20> Active Power Smoothing - On/Off 1 = ON, 0 = OFF --- <21> Volt-Watt – Curve Index Curve Index AO173 <22> Frequency-Watt Curve – Curve Index Curve Index AO186 <23> Frequency-Watt Curve – High Hysteresis High Frequency Hysteresis Curve Index AO187 <24> Frequency-Watt Curve – Low Hysteresis Low Frequency Hysteresis Curve Index AO188 <25> Constant VArs - Percent of Maximum Constant VArs Reactive Power Target AO203 <26> Fixed Power Factor - Power Factor Fixed Power Factor Setpoint AO210 <27> Volt-VAr – Curve Index Curve Index AO217 <28> Watt-VAr – Curve Index Curve Index AO226 <29> Power Factor Correction - On/Off 1 = ON, 0 = OFF --- <30> Reserved - For pricing mode Pricing Mode Setpoint AO241

Each schedule may consist of up to 100 curve points. Time values in a schedule must increase so that the schedule describes a curve, or the outstation may return the INVALID PARAMETER internal indication when the master tries to write the value. The outstation may provide some pre-configured schedules, in which case the master does not necessarily need to modify them. In this profile, it is possible for the master to define the priority of schedules, such that if two schedules that control the same parameter (e.g. Watts output) are running at the same time, the one with the higher priority is considered to have control of that parameter. The outstation shall evaluate and start using each curve only at the moment when the master writes the identity of the schedule to the Selected Schedule Ready (BO-S)

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Only one of these additional schedules can be edited or viewed at a time, as described in section 2.3.3. The Schedule Edit Selector point (AO-S) determines which schedule is “visible” for editing and viewing. Table 59 – Steps to create and enable schedules Data Point Step Description Optionality Function Codes Type Number Select which schedule to edit. This is the “index” of the schedule, not its “identity”. The indexes shall be the monotonically 1. Optional Direct Operate / Response AO S increasing integers 12, 13, 14 .etc. while the curve identities may be any unique number. Set the identity of the schedule to a 2. Required Direct Operate / Response AO S + 1 unique number. 3. Set the priority for the schedule Optional Direct Operate / Response AO S + 2 Set the meaning of the Y-values of the 4. schedule, i.e. the schedule type. Refer to Optional Direct Operate / Response AO S + 3 Table 58 Set the date and time for the schedule to S + 4, 5. Required Direct Operate / Response AO start S + 5 6. Set the repetition interval Required Direct Operate / Response AO S + 6 7. Set the units of the repetition interval Requeired Direct Operate / Response AO S + 7 Every other Set the Time Offset (X-Value) for each point 8. Optional Direct Operate / Response AO schedule point. starting with S+9 Every other Set the Schedule Value (Y-Value) for point 9. Optional Direct Operate / Response AO each schedule point starting with S+10 Set the number of points used for the 10. Optional Direct Operate / Response AO S + 8 schedule.

Enable the Schedule by changing its state Select / Response, 11. Required BO S to “ready” Operate / Response

Check that outstation validates the 12. Required Read BI S+1 selected schedule

If desired, set the day of the week for the Select / Response, S+1 13. Optional BO schedule to repeat Operate / Response through S+7

14. Be notified when the schedule is running Optional Read AI S+10

2.10 Interaction Between Settings Because there are so many different PV and storage functions that can be performed using this profile, it is important to define what happens when two or more of these functions are applied at the same time. This section provides that definition.

2.10.1 Local State The purpose of “local” state is to block commands from offsite sources to enable safe local maintenance and diagnostics and to provide a means for secure onsite management. When an outstation is placed in “local” state, it is to only respond to commands originating from an onsite source. These local commands might be via a local communication port, direct controls at the outstation, or other local interface

Page 236 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs) mechanisms as selected by manufacturers. The means by which the outstation determines which communications are “onsite” and which are “offsite” are outside the scope of this specification. Notionally, the commands to place an outstation an “local” state and to return it to normal state are initiated onsite. When the outstation is in “local” state, the outstation shall not permit the master to perform any of the active functions described in this specification. The “local” state can be read by the master in BI10. Local State overrides Lockout State.

2.10.2 Lockout State Lockout state is similar to local state except that in this case another authorized party (e.g. another master station or the owner/operator) has taken control of the system, thus preventing this master from controlling the device. A master may put the DER into lockout state using BO0. When the outstation is in “lockout” state, the outstation shall not permit the master to perform any of the active functions described in this specification. A master may read the lockout status of the DER from BI11.

2.10.3 Priority of Last Command The outstation shall give priority to whichever function is applied most recently. Consider the following example: 1. At 8:00 am, the master programs a schedule, starting immediately, for the outstation to start delivering 50% maximum generation until 4:00 pm, at which time it is to start delivering 75% maximum generation until midnight. The outstation begins executing the program. 2. At 3:00 pm, a master sends commands to manually adjust the maximum generation to 25% (Function INV2). The outstation adjusts its output accordingly. 3. At 4:00, the previously scheduled event occurs and the outstation changes to 75% maximum generation as instructed. 4. When the schedule ends at 12:00 midnight, the outstation remains at 75% maximum generation because that is what it was last commanded to do. It does not, for instance, return to 25%. Note that throughout this process, the outstation remains in Active Power Limit Mode, as shown by the appropriate binary input point. The schedule also remains in place, as shown by the appropriate analog input point. The two rules are therefore: • The outstation behaves according to whichever message, mode, curve or schedule most recently commanded it. • The outstation does not “remember” what it was doing before the previous command. In the absence of a new command, it continues what it was last commanded to do.

2.10.4 Compatibility and Priority of Modes and Functions It is possible for several different limits and intelligent control functions for distributed energy resources to be in effect simultaneously. In many cases multiple limits or control functions that affect the same parameter, such as Watts or VARs output, may be active at the same time. The purpose of this section is to specify the way these settings behave when simultaneously active. Table 60 illustrates the most general relationship between the various settings in the “Configuration and SCADA” category of analog outputs and the behavior of the DER.

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Table 60 – Settings Affecting Priority of DER Behavior Priority Examples Description A system cannot produce power that it does not have available and may have other practical limits related to its present circumstances. Although 1st these limitations do not show up as analog outputs, they do establish the ( Highest ) Energy Source or Self- ultimate limits of the system. This would for example include any limits Fundamental Imposed Limits on Wattage that result from availability of solar resources or limits that an Physical Limits inverter imposes on itself, based on thermal conditions, errors, failures, etc. No other setting or condition may cause an inverter to violate these self-imposed limits. Nameplate Maximum Voltage Rating (AI3) 2nd These parameters specify a value that is inherent to the DER and does Nameplate Nameplate Active not change during the operation of the DER. These are fixed and and Device discoverable limits. Limits Generation Power Rating at Unity Power Factor (AI4)

3rd Maximum Voltage (AI39) These parameters may be changed during the lifetime of the DER. Some

Present may be changed by the DER, while others may be changed via DNP3 by Operating Maximum Active the master. Limits Generation Power (AI32)

These parameters establish the relationship between the various operating modes of the DER.

Each operating mode has a “priority” analog output which describes the relationship of that mode to the other modes. Lower numbers are higher priority.

Table 61 illustrates the compatibility of operating modes. The value in each cell describes the relationship between two modes: Active Power Limit Mode • (C) indicates the modes are compatible and can run 4th Priority (AO79) simultaneously regardless of how priority is set. Operating • (P) indicates the modes can co-exist as long as relative priority Mode Priority Charge-Discharge Mode is established. For each of the two these modes, the priority Priority (AO89) setting must be different so it is clear which mode has greater priority. • (M) indicates the modes are mutually exclusive and cannot be simultaneously active. If one of the two mutually exclusive modes is already running and the master attempts to enable the second mode, the outstation shall respond with a PARAMETER ERROR internal indication to indicate the enabling of the second mode is not permitted.

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Table 61 – Compatibility of Modes

Emergency Modes Active Power Modes Reactive Power Modes

Disgchg

LEGEND -

e Current

C = Compatible regardless of priority Throuth

Watt

P = Priority must be different to co-exist Through

Watt Curve Watt -

M = Mutually Exclusive, cannot co-exist -

Discharge Storage Discharge

VAR

Watt Control VAR -

- -

VoltageRide FrequencyRide DynamicReactiv DynamicVolt Frequency Charge CoordinatedCharge ActiveLimit Power Active Power Response AutomaticControl Generation ActivePower Smoothing Volt Frequency PricingSignal FixedPower Factor Volt Watt Power FactorCorrection Voltage Ride-Through Frequency Ride-Through C Emergency Dynamic Reactive Current C C Modes Dynamic Volt-Watt C C C Frequency-Watt C C C C Charge-Discharge Storage C C C C C Coordinated Charge-Discharge C C C C C C Active Power Limit C C C C C C C Active Power Response31 Active C C C C C C C P Power Automatic Generation Control C C C C C C C P M Modes Active Power Smoothing C C C C C C C P P M Volt-Watt C C C C C C C P P M P Frequency-Watt Curve C C C C M C C C P C C C Pricing Signal C C C C C C C C C C C C C Fixed Power Factor C C C C C C C C C C C C C C Reactive Volt-VAR Control C C C C C C C C C C C C C C M Power Modes Watt-VAR C C C C C C C C C C C C C C M P Power Factor Correction C C C C C C C C C C C C C C M P P

31 Active Power Response may be configured as Peak Power Limiting, Load Following, or Generation Following modes. These modes can co-exist with each other if their priorities are different (P).

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2.11 Grid Configurations and Islanding The term “grid configuration” is used in this profile to refer to the structure of the grid or power system into which the DER is connected. Specifically, it recognizes that the topology of this power system may change for a variety of reasons, including switch operations that might reconfigure the circuit (e.g. networked feeders), formation of large area or small area islands, alternate modes of grid operation, etc. These are all referred-to as “grid configurations” herein. This profile defines parameters specifying how the DER will automatically switch to alternate settings when the local grid configuration changes, such as when islanding and circuit switching takes place.

2.11.1 Possible Grid Configurations This profile assumes there may be many different grid configurations. It defines standard numbers for the following minimum set: <0> Not Used <1> Unspecified / Autonomously Determined <2> Factory Configuration <3> Default Configuration / Communications Lost <4> Normal Grid-Connected Configuration <5> Islanded Condition 1 (small, local island) <6> Islanded Condition 2 (larger, area island) <7> Islanded Condition 3 (largest, regional island) <8> 1st Alternate Grid-Connected Configuration <9> 2nd Alternate Grid-Connected Configuration <10> 3rd Alternate Grid-Connected Configuration <11-255> Reserved for future assignment

2.11.2 Settings Groups To adjust to changing grid configurations, the outstation shall contain within its memory multiple copies of all its settings, including setpoints, curves, modes and schedules, as illustrated in Figure 35. These “settings groups” shall include: • All of the Analog Outputs in the profile except those controlling the settings groups themselves (AO18 and AO19) • All of the Binary Outputs in the profile except the Disconnect Switch (BO5) and those controlling the settings groups (BO6 and BO7) The settings groups shall not include any of the Binary Inputs, Double-Bit Binary Inputs, Counters, Analog Inputs, Device Attributes (including nameplate data), Logs or other data types defined in the profile. The number of settings groups supported by any outstation is a local decision based on available resources. Just as manufacturers may choose which standard functions to support, it is suggested that they may also choose to limit which settings are actually different from one settings group to another. NOTE: Although these settings groups share a name and perform a similar function to the mechanism in IEC 61850 known as “settings groups”, the mechanism and the manner of its use are completely different.

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Figure 35 – Settings Groups

2.11.3 Settings Group Control Parameters Figure 36 illustrates how settings groups can be edited, viewed and switched based on a few parameters. The boxes in the center of the figure represent the various settings groups, with the green shapes inside each box representing the various settings, arrays, schedules, and other parameters that are included in each group. The switch shown to the left provides a means by which a master can write-to a selected settings group. The group being written-to may or may not be presently active. The switch shown to the right determines which settings group is presently active. As indicated by the “Decision Logic” block, the active settings group may be determined by whatever is presently requested via the communication channel, but may also be determined by a range of additional factors. The following points implement the parameters shown in Figure 36: • Requested Settings Group (AO18) • Active Settings Group (AI68) • Settings Group Being Edited (AO19)

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Figure 36 – Parameters for Controlling Settings Groups

2.11.4 Sensing the Grid Configuration As illustrated in Figure 37, a variety of factors in addition to the Requested Settings Group written by the master may affect the selection of the Active Settings Group by the outstation.

Figure 37 – Possible Inputs Determining Active Settings Group

One of the most important factors is that the outstation may be capable of automatically detecting its grid configuration (particularly, whether it is islanded or not). The master may enable or disable this capability by writing to the Enable Sensed Grid Config Detection binary output point (BO7). However, even if Sensed Grid Config Detection is disabled by the master, the Active Settings Group may still differ from the Requested Settings Group depending on the decision logic and other parameters.

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2.11.5 Modes of Operation When Islanded When islanding takes place, the outstation may behave in one of two modes, as illustrated in Figure 38: • Isochronous mode, in which the DER attempts to control the voltage and frequency within the islanded section of the grid. Isochronous mode is intended to be something like a PID control mode in which the isochronous DER attempts to control to an absolute value of frequency and voltage independent of Watt/VAR load up to the limits of the machine’s capabilities. In effect, the isochronous machine operating in an islanded scenario assumes the role played by the utility in a non-islanded scenario. It ignores the various curves and modes it would normally use in grid-connected configuration. • Droop mode, in which the DER supports the efforts of a DER in isochronous mode using Volt/VAR curves, load/generation following and other functions, as it did when connected to the grid. DERs in droop mode are intended to follow the lead of an isochronous DER, utilizing the previously defined Volt/VAR curve function and Frequency/Watt curve functions, but using alternate settings as defined for the particular islanded condition, to achieve the desired droop characteristics. A DER acting in droop mode behaves similarly to when it was connected to the grid, but using a different set of curves and parameters. The data point Islanded Mode (BO6) determines which of these two modes the outstation shall use in the Islanded grid configurations.

Figure 38 – Grid Configuration and Islanding Context

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2.12 Implementation Table Table 62 shows the DNP3 objects and function codes that shall be supported by the master and outstation implementing this profile. Devices may support objects and function codes beyond those listed in this table, by agreement between master and outstation. This table represents a Level 2 implementation, as discussed in 1.2 of this profile. As discussed in 2.2.8, floating-point analog inputs and outputs, as well as 32-bit analog outputs are not part of the minimum requirements but are recommended enhancements.

Table 62 – DNP3 Implementation Table for the DNP3 DER Profile REQUEST RESPONSE DNP OBJECT GROUP & VARIATION Master may issue Master must parse Outstation must parse Outstation may issue Function Qualifier Function Qualifier Group Var Description Codes Codes Codes Codes Num Num (dec) (hex) (dec) (hex)

1 0 Binary Input – Any Variation 1 (read) 06 (no range,or all)

1 1 Binary Input – Packed format 129 (response) 00, 01 (start-stop)

1 2 Binary Input – With flags 129 (response) 00, 01 (start-stop)

06 (no range, or all) 2 0 Binary Input Event – Any Variation 1 (read) 07, 08 (limited qty)

06 (no range, or all) 129 (response) 2 1 Binary Input Event – Without time 1 (read) 17, 28 (index) 07, 08 (limited qty) 130 (unsol. resp)

06 (no range, or all) 129 (response) 2 2 Binary Input Event – With absolute time 1 (read) 17, 28 (index) 07, 08 (limited qty) 130 (unsol. resp)

06 (no range, or all) 129 (response) 2 3 Binary Input Event – With relative time 1 (read) 17, 28 (index) 07, 08 (limited qty) 130 (unsol. resp)

10 0 Binary Output – Any Variation 1 (read) 06 (no range,or all)

10 2 Binary Output – Output status with flags 129 (response) 00, 01 (start-stop)

3 (select) 4 (operate) 12 1 Binary Command – Control relay output block (CROB) 17, 28 (index) 129 (response) echo of request 5 (direct op) 6 (dir. op, no ack)

1 (read) 7 (freeze) 20 0 Counter – Any Variation 8 (freeze noack) 06 (no range,or all) 9 (freeze clear) 10 (frz. cl. noack)

20 1 Counter – 32-bit with flag 129 (response) 00, 01 (start-stop)

21 0 Frozen Counter – Any Variation 1 (read) 06 (no range,or all)

21 1 Frozen Counter – 32-bit with flag 129 (response) 00, 01 (start-stop)

21 9 Frozen Counter – 32-bit without flag 129 (response) 00, 01 (start-stop)

06 (no range, or all) 22 0 Counter Event – Any Variation 1 (read) 07, 08 (limited qty)

30 0 Analog Input – Any Variation 1 (read) 06 (no range,or all)

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REQUEST RESPONSE DNP OBJECT GROUP & VARIATION Master may issue Master must parse Outstation must parse Outstation may issue Function Qualifier Function Qualifier Group Var Description Codes Codes Codes Codes Num Num (dec) (hex) (dec) (hex)

30 1 Analog Input – 32-bit with flag 129 (response) 00, 01 (start-stop)

30 2 Analog Input – 16-bit with flag 129 (response) 00, 01 (start-stop)

06 (no range, or all) 32 0 Analog Input Event – Any Variation 1 (read) 07, 08 (limited qty)

129 (response) 32 1 Analog Input Event – 32-bit without time 17, 28 (index) 130 (unsol. resp)

129 (response) 32 2 Analog Input Event – 16-bit without time 17, 28 (index) 130 (unsol. resp)

40 0 Analog Output Status – Any Variation 1 (read) 06 (no range,or all)

40 2 Analog Output Status – 16-bit with flag 129 (response) 00, 01 (start-stop)

3 (select) 4 (operate) 41 2 Analog Output – 16-bit 17, 28 (index) 129 (response) echo of request 5 (direct op) 6 (dir. op, no ack)

50 1 Time and Date – Absolute time 2 (write) 07 (limited qty = 1)

50 3 Time and Date – Last Recorded Time32 2 (write) 07 (limited qty = 1)

129 (response) 07 (limited qty) 51 1 Time and Date CTO – Absolute time, synchronized 130 (unsol. resp) (qty = 1)

129 (response) 07 (limited qty) 51 2 Time and Date CTO – Absolute time, unsynchronized 130 (unsol. resp) (qty = 1)

07 (limited qty) 52 1 Time Delay – Coarse 129 (response) (qty = 1)

07 (limited qty) 52 2 Time Delay – Fine 129 (response) (qty = 1)

60 1 Class Objects – Class 0 data 1 (read) 06 (no range,or all)

06 (no range, or all) 60 2 Class Objects – Class 1 data 1 (read) 07, 08 (limited qty)

06 (no range, or all) 60 3 Class Objects – Class 2 data 1 (read) 07, 08 (limited qty)

06 (no range, or all) 60 4 Class Objects – Class 3 data 1 (read) 07, 08 (limited qty)

00 (start-stop) 80 1 Internal Indications – Packed format 2 (write) index=7

0 (confirm), 13 (cold restart)33 No Object (function code only) 23 (delay meas.) 24 (record current 34time)

32 Time and Date -Last Recorded Time (g50v3) shall be supported when time synchronization is performed over Internet Protocols 33The outstation must permit the Cold Restart function code to be disabled for security or safety reasons, per TB2014-001 34 The Record Current Time function code shall be supported when time synchronization is performed over Internet Protocols Page 245 2018-08-22 AN2018-001 DNP3 Profile for Communications with Distributed Energy Resources (DERs)

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2.13 Mapping to IEEE Std 1547-2018 Table 63 identifies which points from this profile correspond to the information specified as mandatory for DER communications in IEEE Std 1547-2018: IEEE Standard for Interconnection and Interoperability of Distributed Energy Resources with Associated Electric Power Systems Interfaces. Table 63 - Mapping of IEC Std 1547 to The DNP3 DER Profile Category Information Units Output(s) Input(s) Monitored Active Power Watts n/a AI537 Information Reactive Power VArs n/a AI541 Voltage Volts n/a AI547 - AI553 Current Amps n/a AI554 - AI556 Frequency Hz n/a AI536 Operational State / Connection Status On/Off/others… n/a BI10 - BI24 Alarm Status Alarm / No-Alarm n/a BI0 - BI9 Operational State of Charge Percent n/a AI48 Nameplate Active Power Rating at Unity Power Factor Watts n/a AI4 Information Active Power Rating at Specified Over-excited Watts n/a AI6 - AI7 (Energy) Power Factor Specified Over-excited Power Factor Unitless n/a AI8 Active Power Rating at Specified Under- Watts n/a AI9 - AI10 excited Power Factor Specified Under-excited Power Factor Unitless n/a AI11 Reactive Power Injected Maximum Rating VArs n/a AI12 Reactive Power Absorbed Maximum Rating VArs n/a AI13 Active Power Charge Maximum Rating Watt n/a AI5 Apparent Power Charge Maximum Rating VA n/a AI15 Storage Actual Capacity Wh n/a AI16 Nameplate AC Voltage Nominal Rating RMS Volts n/a AI29 - AI30 Information AC Voltage Maximum Rating RMS Volts n/a AI3 (RMS) AC Voltage Minimum Rating RMS Volts n/a AI2 AC Current Maximum Rating RMS Amperes n/a AI19 - AI20 Namplate Supported Control Mode Functions List of Yes/No n/a BI31 - BI51 Information Normal operating performance category A/B n/a AI22 (other) Abnormal operating performance category I/II/III n/a AI23 Reactive Susceptance that remains connected Siemens n/a AI21 Manufacturer Text n/a Refer to 2.4.1 Model Text n/a Refer to 2.4.1 Serial Number Text n/a Refer to 2.4.1 Version Text n/a Refer to 2.4.1 Enter Service Permit service Enabled/Disabled BO3 BI16 ES Voltage High Percent Nominal AO6 AI50 ES Voltage Low Percent Nominal AO7 AI51 ES Frequency High Hz AO8 AI52 ES Frequency Low Hz AO9 AI53 ES Delay Seconds AO10 AI54 ES Randomized Delay Seconds AO11 AI55 ES Ramp Rate Seconds AO12 AI56 Active Power Limit Active Power Enable On/Off BO17 BI69

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Category Information Units Output(s) Input(s) Limit Mode Maximum Active Power Watts AO87 - AO88 AI148 - AI149 Constant Constant Power Factor Enable On/Off BO28 BI80 Power Factor Constant Power Factor Unitless AO210 - AO211 AI288 - AI289 Mode Constant Power Factor Excitation Over/Under BO10 - BO11 BI29 - BI30 Volt-VAr Mode Voltage-Reactive Power (Volt-VAr) Enable On/Off BO29 BI81

VRef (Reference Voltage) Volts AO0 - AO1 AI29 - AI30

Autonomous VRef Adjustment Enable On/Off BO41 BI93

VRef Adjustment Time Constant Seconds AO220 AI300 V/Q Curve Points (x,y) Volts, VArs AO217, AI303 AO244 - AO448 Open Loop Response Time Seconds AO218 - AO219 AI298 - AI299 Watt-VAr Mode Active Power-Reactive Power (Watt-VAr) On/Off BO30 BI82 Enable P/Q Curve Points (x,y) Watts, VArs AO226, AI308, AO244 - AO448 AI328 - AI532 Constant VAr Constant Reactive Power Mode Enable On/Off BO27 BI79 Mode Constant Reactive Power VArs AO203 AI281 Volt-Watt Mode Voltage-Active Power (Volt-Watt) Mode Enable On/Off BO25 BI77 V/P Curve Points (x,y) Volts, Watts AO173, AI248, AO244 - AO448 AI328 - AI532 Open Loop Response Time Seconds AO175 - AO176 AI251 - AI252 Voltage Trip HV Trip Curve Points (x,y) Seconds, Volts AO23, AI73 AO244 - AO448 AI328 - AI532 LV Trip Curve Points (x,y) Seconds, Volts AO24, AI74, AO244 - AO448 AI328 - AI532 Momentary HV Momentary Cessation Curve Points (x,y) Seconds, Volts AO25, AI75, AI328 - Cessation AO244 - AO448 AI532 LV Momentary Cessation Curve Points (x,y) Seconds, Volts AO26, AI76, AO244 - AO448 AI328 - AI532 Frequency Trip HF Trip Curve Points (x,y) Seconds, Hz AO28, AI79, AO244 - AO448 AI328 - AI532 LF Trip Curve Points (x,y) Seconds, Hz AO29, AI80, AO244 - AO448 AI328 - AI532

Frequency Over-frequency Droop Deadband DBOF Hz AO62 - AO63 AI121 - AI122 Droop Under-frequency Droop Deadband DBUF Hz AO66 - AO67 AI125 - AI126 (Frequency- Watt) Over-frequency Droop Slope KOF Watts per Hz AO64 - AO65 AI123 - AI124 Under-frequency Droop Slope KUF Watts per Hz AO68 - AO69 AI127 - AI128 Open Loop Response Time Seconds AO72 - AO73 AI131 - AI132

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3 Conclusions This application note defines how Distributed Energy Resource (DER) functions defined by the EPRI report Common Functions for Smart Inverters and captured in IEC 61850-7-420 shall be implemented using DNP3. The profile defined here is designed so the data reported by the outstation can be easily mapped onto a standard IEC 61850-7-420 distributed energy resource implementation.

4 Submitted By Electric Power Research Institute 3420 Hillview Avenue, Palo Alto, California 94304-1338 PO Box 10412, Palo Alto, California 94303-0813 USA 800.313.3774 ▪ 650.855.2121 ▪ [email protected] ▪ www.epri.com

Prepared by: EnerNex 620 Mabry Hood Road Suite 300 Knoxville, TN 32769 USA 865.218.4600 ▪ www.enernex.com

Tesco Automation 340 Emerald Park Road Emerald Park SK S4L 1C7 Canada 306.949.2162 ▪ www.tesco-group.com, www.tescoautomation.com

5 Disclaimer Application Notes contain application information developed by users and are provided for the benefit of other users. This note illustrates how the features of DNP3 are used to meet specific user requirements. This Application Note has been reviewed by the DNP Technical Committee. It does not contain all of the details that are mandatory for a complete DNP3 implementation, and the Committee does not warrant that the approach taken is the only way to use DNP3 to meet the user requirements.

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