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P2030 Smart Grid Standard Text Submittal Form This text is intended as proposed text for consideration of the P2030 Writing Group to the P2030 Draft Guide for Smart Grid Interoperability of Energy Technology and Information Technology Operation with the Electric Power System (EPS), and End-Use Applications and Loads. SUBMITTAL INFORMATION DATE SUBMITTED: 6/28/2017 SUBMITTED BY: P2030-TF1 Distribution working group AFFILIATION: EMAIL: TEXT PLACEMENT INFORMATION IN THE P2030 OUTLINE DRAFT (MENTOR DOC#180-2010): CLAUSE #: 6 CLAUSE HEADING: DISTRIBUTION DOMAIN PROPOSED TEXT 6.3.1.3 Distribution domain The Distribution EPS (Figure 9) includes actors located throughout the electric power system. The distribution substation actor represents many components located on a common site that cannot be assigned to the distribution protection and control devices actor nor the distribution sensors and measurement devices actor. In addition the distribution energy resource (DER) actor represents generation and storage of all kinds that are connected directly to the distribution EPS but not through a load customer interconnection, recognizing that there are also DER in the customer domain. 1|Pa g e CONTROL/OPERATIONS D8 MARKETS D2 D4 Distribution Protection and Control Devices D5 Distribution Substation D10 TRANSMISSION D1 D11 D14 D3 D17 D7 D15 Sensors and Measurement Devices Distributed Energy Resource (DER) D16 D9 D6,D20 D12 D21 DISTRIBUTION BULK GENERATION SERVICE PROVIDERS CUSTOMER Figure 9 – Distribution domain of the power interoperability perspective The distribution domain has strong data paths to the distribution operation/control actor in the operations/control domain. These data paths reflect the centralized control of the distribution EPS from the distribution control center. The distribution domain may also have a data path to the transmission substation actor in the transmission domain, representing only protection and control systems. 6.4.1.1 Information transfer time Information transfer time is the time from when the first byte of information from the transmitting application layer to when the information is delivered to the receiving application layer (i.e. first byte sent by source application to last byte received by destination application). The transfer time includes the communications system latency (i.e. is technology and path dependent), and any required connection time (e.g. dial-up). Without these inclusions, there should not be a need to define information transfer time. Various distribution domain functions will have not-to-exceed transfer time requirements (sometimes referred to as “tolerable delay” or “latency”) which must be met by the communications system: ∙ Tele-Protection (people or equipment safety) - Low latency of ~1ms is for networked systems (e.g. transmission system or closed-loop distribution network) where there are issues with transient stability; latency of up to ~2cycles for open-loop systems. ∙ Control/Monitor (operator/computer decision to improve reliability/efficiency) Medium to High latency of up to 3s depending on the functional requirements of the computer system (e.g. DMS or EMS or Advanced Applications), and within 2s of the formation of an unintentional DR island. ∙ Billing (financial support or historical information) - High latency of a few hours or longer depending on the billing functional requirements (e.g. monthly, Time-of-Use, Critical Peak Pricing, Demand Response, Remote disconnect-reconnect, etc.). 2 ∙ File Transfer - Medium latency for transfer of event data, firmware, settings, etc. 6.4.1.2 Latency Latency is channel access delay plus the propagation delay (first byte transmitted on the medium to first byte received at the destination), including queuing and processing delays but not any time required by the source or destination application to aggregate data, incorporate data into protocols and perform data verification. Queuing delay occurs when a gateway receives multiple packets from different sources heading towards the same destination. Since typically only one packet can be transmitted at a time, some of the packets must queue for transmission, incurring additional delay. Processing delays are incurred while a gateway determines what to do with a newly received packet. The combination of propagation, serialization, queuing, and processing delays often produces a complex and variable network latency profile. The aggregate latency shall meet the total of all latency expected between the sender and the receiver and may represent the accumulated latency of multiple latency actions. Define jitter? 6.4.1.3 Reliability For the purposes of this guideline, reliability is a measure of the probability of the desired data packet being accurately delivered in the required time, without exception. Reliability also has a qualitative definition to describe functional requirement: ∙ Critical. The failure of information transfer may result in compromised safety or damage to equipment. ∙ Essential. The failure of information transfer may result in inefficient or ineffective operation ∙ Important. The failure of information transfer may result in loss of revenue, damage to public image, or loss of technical information ∙ Non-essential. Not critical, essential, or important. On the distribution domain, tele-protection data is critical, control/monitor data is essential and billing & file transfer data is important. Single path reliability is typically acceptable and is an economics issue (e.g. loss of Tele-Protection relies on backup protection; loss of Control relies on on-site intervention; loss of Monitor relies on previous measurement; loss of Billing relies on on-site intervention) except for extreme circumstances. 6.4.1.4 Data volume A measure of the total amount of data to be carried in a given communications path. For example, the amount of data from one piece of substation equipment, times the number of that kind of equipment in the substation plus the protocol required for the data transmission. 6.4.1.5 Data occurrence interval A data occurrence interval is a length of time between a communication start and a subsequent communication start, which may be periodic (e.g. synchrophasor sample) or a periodic (e.g. voltage reading). Update Frequency is often used to describe the functional requirement: ∙ Synchronous – Updates in much less than a cycle. ∙ Real-time - Updates once every few seconds or more frequently as required by computer system (e.g. DMS or EMS), with provision for on-demand update. 3 ∙ Near real-time - Updates once every five to fifteen minutes or more frequently as required by operator or computer system (e.g. DMS or EMS), with provision for on-demand update. ∙ Historical – Updates once per day or less frequently. 6.4.1.6 Security A measure of the immunity from attack that a given communications function must have. This includes cyber attacks and physical attacks, including electromagnetic attacks. 6.4.1.7 Priority Priority refers to relative importance of communicating the data. Typically aligned with the reliability functional requirements, though a particular critical message can have higher priority than other critical messages. 6.4.1.8 Time Synchronization The timing requirements placed on measurement and control systems are becoming increasingly stringent. Traditionally these measurement and control systems have been implemented in a centralized architecture in which the timing constraints are met by careful attention to programming combined with communication technologies with deterministic latency. Time Synchronization (per IEEE 1588) enables precise synchronization of clocks in measurement and control systems implemented with technologies such as network communication, local computing and distributed objects. 6.4.1.9 Level of assurance Not sure why this is separate from Reliability. 6.4.10 Broadcast method A mechanism to send a single message to a group or all of the devices connected at a particular network layer. 6.5.2 Operations data Bi-directional information and instruction flow requires frequent updating and provides a snapshot of the grid. Examples include tele-protection data and control / monitor data such as electrical quantities, operation modes, demand, energy consumption/production, etc. 6.5.3 Reporting and engineering data Information uploaded on a demand or scheduled basis. Examples include availability, run-time data, oscillography, event files, fault records, firmware updates, setting files, etc. Appendix Monitoring Equipment (Sensors) Reporting Equipment CT, VT Transducer and/or IED Distribution Transformer substation CT, VT Transducer and/or IED Distribution Tap Changer substation IED IED CT, VT Transducer and/or IED Actor Equipment Distribution HV Bus substation Distribution LV Bus substation Metric / Value MVA, MW, MVAR (3ph) Peak Demand w/ local reset MWh throughput Ia, Ib, Ic, In Vab, Vbc, Vca MVA, MW, MVAR (3ph) Oil Temp, Oil Level, Gas in Oil Winding Hotspot Temp LTC Tap Position LTC V Setpoint Ia, Ib, Ic, In Vab, Vbc, Vca Va, Vb, Vc 4 Data Source Transfer Update Time Frequency (Tolerable Delay) Telemetered or Derived Real-time Copper or aluminum conductor Control / found in substation and some Monitor substation equipment Telemetered Real-time Substation incoming power Control / transformer converting Monitor transmission voltage to distribution voltages. Telemetered Real-time Telemetered Real-time Description of Item Control / Built-in or separate tap changer Monitor unit in station transformer Copper or aluminum conductor Control / found in substation and some Monitor substation equipment Actor Equipment Monitoring Equipment (Sensors) Reporting Equipment Metric / Value Data Source Transfer Update Time Frequency (Tolerable Delay) Telemetered Near realtime Description of Item MVA, MW, MVAR (3ph) Harmonic Mean & High Log, Sag/Swell, ITI Disturbances, Voltage Characteristics Distribution substation / SVC - Static Var protection Compensator Self and control or STATCOM contained devices / Static CT, VT sensors and Synchronous measureme Compensator nt devices Distribution Shunt substation Capacitors CB Self contained IED RTU Transducer, Distribution CT or Self Protective Circuit Breaker substation contained CT Relay, IED and/or RTU Distribution Circuit substation / Recloser sensors and (Electronic measureme Controls) nt devices Self contained CT, VT Self contained IED Ia, Ib, Ic, In Vab, Vbc, Vca MVA, MW, MVAR (3ph) Setpoints Status: Open/Close Status: Open/Close Ia, Ib, Ic Fault Current & Tags, Alarms Status: Open/Close Ia, Ib, Ic, In Fault Current & Tags Vab, Vbc, Vca MVA, MW, MVAR (3ph) MWh throughput Equipment used to provide Vars Control / into the distribution system using Monitor semi-conductor or synchronous devices. An assembly of dielectric and electrodes in a container (case), with terminals brought out, that is intended to introduce capacitance into an electric power circuit (See IEEE Std. 18-2002 [B9]). Circuit Breaker - A switching device capable of making, carrying, and breaking currents under normal circuit conditions, and also making, carrying for a specified time, and breaking currents under specified abnormal conditions such as those of short circuit (See IEEE Std. Dictionary 1984 [B1]). Telemetered Near realtime Control / Monitor Telemetered Near realtime Control / Monitor and/or TeleProtection Telemetered Near realtime Device that interrupts the circuit Control / on a fault than attempts to close Monitor back in 1 or more times, typically with some time delay. Station Service and Power Supply Distribution (Batteries, substation Battery Chargers, Backup Generator) Self Self Alarms Telemetered Near realtime Batteries - Source of control voltage power for substation equipment. Battery Chargers - Equipment that converts ac power to dc power and is used to recharge and maintain a station battery in a fully charged condition and to supply power to dc loads during normal operation (See IEEE Std. 650-2006 [B16]). Control / Backup Generator - An Monitor independent source of standby electrical power that consists of a diesel-fueled internal combustion engine (or engines) coupled directly to an electrical generator (or generators); the associated mechanical and electrical auxiliary systems; and the control, protection, and surveillance systems (See IEEE Std. 387-1995 [B11]). Distribution Communicatio substation / n (fibre, sensors and microwave, measureme copper, radio, nt devices etc.) Self Self Alarms Telemetered Near realtime Control / Monitor Telemetered Near realtime Telemetered Near realtime Distribution Weather substation Station Self Self Lat/Long, Ambient Air Temperature, Wind Speed, Humidity, Cloud Opacity Security Distribution Camera & substation Devices Self Self Alarms, Audio/Video 5 Equipment and procedures to monitor and report weather Control / conditions that may affect the Monitor operation of the power network (See IEEE Std. 1646-2004 [B24]). Remote visual monitoring, perimeter monitoring, intrusion detection, and door/access panel Control / open/close monitoring to help Monitor protect hardware and software from accidental or malicious access, use, modification, destruction, or disclosure. Actor Equipment Monitoring Equipment (Sensors) Reporting Equipment Metric / Value Data Source Transfer Update Time Frequency (Tolerable Delay) Description of Item Security cameras can include normal CCTV, low-light and infrared systems. Intrusion detection systems encompass a wide range of technologies. Typically system alarms and indications are centrally monitored or relayed to appropriate manned workstations to facilitate timely evaluation and response. Security also pertains to personnel, data, communications, and the physical protection of computer installations (See IEEE Std. 1547.32007 [B23]). Distribution protection Shunt and control Capacitors devices / (Electronic sensors and Controls) measureme nt devices Distribution protection Voltage and control Regulators devices / (Electronic sensors and Controls) measureme nt devices Distribution protection and control Circuit devices / Interrupter/ sensors and sectionalizer measureme nt devices Distribution protection O/H Switch and control (Supervisory) devices Distribution protection and control UG Switchgear devices / (Electronic sensors and Controls) measureme nt devices Distribution FCI - Faulted sensors and Circuit measureme Indicators nt devices Self contained IED Ia, Ib, Ic, In Vab, Vbc, Vca MVA, MW, MVAR (3ph) Setpoints Telemetered Near realtime An assembly of dielectric and electrodes in a container (case), Control / with terminals brought out, that is Monitor intended to introduce capacitance into an electric power circuit (See IEEE Std. 18-2002 [B9]). Self contained CT, VT Self contained IED Ia, Ib, Ic, In Vab, Vbc, Vca MVA, MW, MVAR (3ph) MWh throughput Tap Position V Setpoint Telemetered Near realtime Device that attempts to keep the Control / voltage on a distribution line Monitor within an acceptable range. Self contained CT, VT Self contained IED Status: Open/Close Ia, Ib, Ic, In Vab, Vbc, Vca MVA, MW, MVAR (3ph) Telemetered Near realtime Device typically used to switch Control / equipment; designated fault Monitor interrupters are able to interrupt fault current. Self RTU Status: Open/Close Telemetered Near realtime Able to interrupt voltage; Control / designated load-break are able to Monitor interrupt load current. Self contained CT, VT Self contained IED Status: Open/Close Ia, Ib, Ic, In Vab, Vbc, Vca MVA, MW, MVAR (3ph) MWh throughput Telemetered Control / Monitor Near realand/or time TeleProtection Self Contained CT RTU Fault Indication, I, pf, Fault Current Telemetered Near realtime Distribution sensors and Amp Meter measureme nt devices Self Contained CT Transducer and/or IED I, pf, Ireal Telemetered Near realtime Distribution sensors and Power Meter measureme nt devices Self contained CT, VT Transducer and/or IED MWh throughput, MVA, MW, MVAR, V, PQ, Alarms, Temperature Telemetered Near realtime Distribution sensors and Ductbanks / measureme Manholes nt devices Transducer Temperature, Status of Transducer Auxiliary Equipment (e.g. sump Telemetered pumps) Near realtime Control / Monitor Customer Billing meters Self Self MWh throughput, MVA, MW, MVAR, V, PQ, Alarms Telemetered Near realtime Billing and/or Meters used by end customers to Control / monitor and record consumption. Monitor Demand Customer Response Controls Self Self Undetermined Telemetered Near realtime Control / Monitor Self contained CT, VT 6 Device that consists of electrical disconnects, fuses, circuit breakers/interrupters and/or motor operators used to isolate faults, energize or de-energize equipment. Control / Monitor Instrument transformer that converts power level currents to Control / smaller levels that can be handled Monitor by monitoring and protection devices. Discrete instrument transformers, installed on the circuit or on the distribution transformer, that Control / converts power level voltages to Monitor smaller levels that can be handled by monitoring and protection devices. Actor Equipment Distributed Distributed energy Resource resource Customer / Distributed Microgrid energy resource Monitoring Equipment (Sensors) Self Self Reporting Equipment Metric / Value Self Ia, Ib, Ic, In Vab, Vbc, Vca MVA, MW, MVAR (3ph) MWh throughput Setpoints Self Ia, Ib, Ic, In Vab, Vbc, Vca MVA, MW, MVAR (3ph) MWh throughput Setpoints Transfer Update Time Description of Item Frequency (Tolerable Delay) Control / Near real- Monitor Generation located along the Telemetered time or and/or distribution lines, and distribution Real-time Telesubstations. Protection A DR island system that can separate and isolate itself from Control / the Distribution EPS seamlessly Near real- Monitor with little or no disruption or Telemetered time or and/or power quality impact to the loads Real-time Teleand can automatically Protection resynchronize and reconnect itself to the Distribution EPS in a seamless fashion. Data Source The following reporting equipment are used to provide the Parameters are listed in the Metric/Value column above: Transducer - Metering equipment that continuously monitors electric parameters. PLC - Programmable Logic Controller - Digital control system with programming capability that performs functions similar to a relay logic system (See IEEE Std. 1010-2006 [B18]). Protective Relay - An assembly usually consisting of current and voltage circuits, measuring units, logic, and power supplies to provide a specific relay scheme, such as line, transformer, bus, or generator protection. A relay system may include connections to other systems, such as data logging, alarm, communications, or other relay systems (See IEEE Std. C37.90.1-2002 [B5]). DFR - Digital Fault Recorder - Monitoring device that captures transient and longer term events such as fault signatures. IED - Intelligent Electronic Device - Using some level of logic use data from their sensors and data communicated to them to perform an action. Common IED's include protection syste.ms and controllers for various equipment such as load tap changers, capacitors, etc., and can also include DFR functionality. RTU - Remote Terminal Unit - Connects local equipment to SCADA to transmit telemetry data and/or control/report status. Usage: HMI - Human Machine Interface - For local control/monitoring by the distribution substation actor. Includes keyboards, displays, keypads, touch screens, and similar devices to allow human interaction with a system (See IEEE Std. 610.12-1990 [B14]). SCADA - Supervisory Control and Data Acquisition - System used by the distribution operation and control actor for monitoring and control of the electric distribution system. DMS - Distribution Management System – A distribution operation and control actor that uses SCADA to provide for centralized visibility and control of the distribution assets with enhanced decision-support capability that will assist in the day-to-day operations of the distribution system. Data Source: Telemetered - Updated via SCADA system to the DMS; proprietary system to peer-to-peer systems; or metering system to enterprise systems. SCADA typically use DNP3 protocol via serial or IP but will require IEC61850 protocol over IP for low latency requirements over a 7 communications network. Metering systems typically use ANSI C12. Data concentrators may be used to reduce the overhead for each message. Derived - Updated by computer system with telemetered and/or other derived data. 8