Content for  TS 22.104  Word version:  19.1.0

A smart distribution transformer terminal is usually deployed in a distribution transformer area. The terminal can support multiple energy applications simultaneously. Multiple kinds of energy data are collected by the terminal and then delivered to a energy application platform. Figure A.4.8-1 illustrates a workflow example for a smart distribution transformer terminal.

In general, the connections between the smart distribution transformer terminal and the energy application platform are provided by the 5G system. The connections between energy end equipment and smart distribution transformer terminal may be provided by 5G system. In this case, about 300 to 500 energy end devices are connected to one smart distribution transformer terminal. The average service bit rate between the smart distribution transformer terminal and an energy end device is more than 2 Mbit/s in uplink for each application. The related communication distance is between 100 m and 500 m. The associated KPI is provided in Table A.4.8-1.

Use case#1:

Distributed energy resources (DER) become increasingly important. The potentially large number of DERs will have an impact on security, stability, and operation efficiency of the energy grid. The integration of DERs into the energy grid poses many challenges for the involved communication system. To incorporate more renewable and alternative energy sources, the communication infrastructure must have the ability to easily handle an increasing amount of data traffic or service requests and must provide a real-time monitoring and control operation for these distributed energy resources. A reliable communication between the DERs is crucial. When it comes to communications architecture, IEC 61850 is a widely used standard for automation and equipment of power utilities and DER, specifically for defining protocols for IEDs (Intelligent electronic devices) at electrical substations The IEC 61850 standard specifies the timing constraints for messages typically used in substations. GOOSE (Generic Object Oriented Substation Events) and SV (Sampled Values) messages are assumed as time critical messages. They have the tightest deadlines (maximum allowed transfer time) among all IEC 61850 messages, corresponding to 3 ms. While GOOSE is typically used for transfering information related to monitoring and control functions (circuit breaker status etc.), SV is used for transfering measurement samples of current and voltage signals. The SV protocol works on a periodic information transmission model, sending messages at a fixed rate. For protection purposes, the default rate is 4000 or 4800 messages per second for 50 and 60 Hz power systems, respectively. On the other hand, the GOOSE protocol operates in a sporadic information transmission model, where a continuous flow of data is maintained to increase communication reliability. The typical sizes of GOOSE and SV messages are160 and 140 bytes, respectively. GOOSE messages are transmitted in two different modes: (1) safe operation: 1 message per second (service bit rate = 1.28 kbit/s); (2) emergency operation: 32 messages per second (service bit rate = 41.0 kbit/s). SV messages are transmitted at much higher rate, namely 4800 messages per second (service bit rate = 5.4 Mbit/s). The associated KPIs are provided in Table A.4.9-1.

Use case#1: Distributed energy resources and micro-grids: using SV(sample value) message with 50Hz Use case#2: Distributed energy resources and micro-grids: using SV(sample value) message with 60Hz Use case#3: Distributed energy resources and micro-grids: using GOOSE message

During emergencies, public mobile land networks (PLMNs) may restrict network access, which may lead to a prohibitevly low communication service availability for machine-type communication (MTC) for Smart Grid applications. An example is communication for microgrids. Microgrids are separate parts of a power grid that can be controlled and operated individually in a so-called island mode, or together with other parts of the power grid. The idea is to prioritise Smart Grid-related communication in order to ensure reliable and available communication for selected devices during emergency conditions. Existing features of a mobile network can be used to differentiate MTC of devices in a microgrid from other kind of MTC traffic or human-to-human communication. These features can help these microgrid devices to have communication service during emergencies. The communication among the microgrid devices enables co-ordination of DERs, which help the DERs can autarkically implement recovery of an islanded microgrid. The associated KPI is provided in Table A.4.10-1.