Systems testing and optimization D6.5

Transcription

1 Real proven solutions to enable active demand and distributed generation flexible integration, through a fully controllable LOW Voltage and medium voltage distribution grid WP6 - Demonstrations in real user environment: ENERGA - Poland Systems testing and optimization D The UPGRID Consortium This project has received funding from the European Union s Horizon 2020 research and innovation programme under grant agreement No

2 PROGRAMME H2020 Energy Theme GRANT AGREEMENT NUMBER PROJECT ACRONYM UPGRID DOCUMENT D6.5 TYPE (DISTRIBUTION LEVEL) Public Confidential Restricted DUE DELIVERY DATE 30/09/2017 DATE OF DELIVERY 28/11/2017 STATUS AND VERSION Final / v08 NUMBER OF PAGES 167 WP / TASK RELATED WP6 / T6.5 WP / TASK RESPONSIBLE AUTHOR (S) PARTNER(S) CONTRIBUTING OFFICIAL REVIEWER/s FILE NAME ENERGA / ENERGA S. Noske, M. Glombiowski, D. Falkowski (ENERGA) K. Swat, D. Bochenski (ATENDE), Adam Babs, Aleksander Babs, Łukasz Kajda, Marcin Tarasiuk (IEN), K. Dobrzyński, Z. Lubośny, J. Klucznik (GUT) TECNALIA (Eduardo García), VATTENFALL (Nicholas Etherden, Peter Söderström) UPGRID_WP6_D6_5_v8_Final 2 167

3 DOCUMENT HISTORY VERS. ISSUE DATE CONTENT AND CHANGES v Outline of document v First part of general description v Completed Chapter 1 and 2 v Complete the Chapter 3, field equipment tests v04b Complete the Chapter 4, IT system tests v Final text verification v Final document v06b New version of final document v Final version after including reviewers comments v Final version to be submitted 3 167

4 EXECUTIVE SUMMARY The energy sector is constantly affected by technological and business trends, as a result of which it undergoes an increasingly faster and deeper transformation. An even more important role in shaping the energy market is played by environmental and climatic conditions, which fact translates directly into legal regulations in the EU and in Poland. A sharp increase is also observed in the area of the use of solutions based on information and communication technologies. A rapid evolution of the Internet, telecommunications and digitization provides end users with tools enabling them to assume new roles in the area of generation and optimization of energy use. The UPGRID demonstration project executed in is focused on studying innovative technologies mostly in Low Voltage (LV) networks. The main objective of the UPGRID project is to develop functionalities in Distribution System Operators (DSOs) which serve the purpose of integration of LV and Medium Voltage (MV) networks with demand-side management and distributed generation. Pertinent work is performed in four demonstration areas: in Poland, Spain, Portugal and Sweden. The research and test results of the Polish demonstration area have been executed within Work Package 6 (WP6). The objective of the Polish demonstration area is, in particular, to build and test new innovative solutions that will enable verification and assessment of selected technologies with regard to improving the reliability and optimization of grid operation, including solutions that support the connection of dispersed generation sources. A key element of the project is the use of an AMI system, which is an important source of data for supporting LV grid operation management. New solutions include: devices for monitoring and supervising the grid, IT systems integrating data from a great number of sources. The demonstration project concerns urban networks. The Polish demonstration area is located in Gdynia City. It includes 55 secondary substations (SSs) which supply nearly 15,000 customers. The MV network consists exclusively of underground cable lines with a total length of 34 km. The LV network includes both, underground cable and overhead lines with a total length of 100 km. WP6 is executed by a consortium made up of the following companies: ENERGA OPERATOR SA (EOP). As a DSO, it plays the role of the leader of the Polish demonstration area executed within WP6. ENERGA-OPERATOR SA runs its business in a territory covering 24% of Poland and delivers electricity to nearly 3 million customers

5 Gdańsk University of Technology. A university with a great tradition, established in It conducts research work, supports DSOs and other participants of the energy market in the development of technologies in the areas of electricity generation, distribution and transmission. The Institute of Power Engineering. The Institute of Power Engineering is a research institute conducting scientific studies and implementation works in the following areas: forecasting and planning the development of power engineering, generation, transmission, distribution and use of electricity, heat and unconventional energy sources. Atende and Atende Software Sp. z o.o. Atende is the holder of a 100% stake in Atende Software Sp. z o.o. Atende Software Sp. z o.o. is a technological partner of ENERGA-OPERATOR SA in the implementation of the AMI system. In addition, Mikronika works as a subcontractor of ENERGA. Mikronika is the supplier of Supervisory Control and Data Acquisition (SCADA) solutions used in the demonstration area. The company is a Polish leader among the suppliers of SCADA/DMS systems and devices for monitoring and supervising power grids. The consortium members have performed WP6 in the following five tasks: T6.1 System Analysis, T6.2 System Design, T6.3 Network infrastructure deployment, T6.4 Information and Communication Technologies (ICT) solutions deployment, T6.5 Systems testing and optimization. This document is a summary of the works completed within T6.5 System testing and optimization. In terms of devices for monitoring and supervising the grid, the following devices have been implemented and tested: Prototype solutions for monitoring and supervising SSs integrated Advanced Metering Infrastructure (AMI)/Smart Grid (SG) cabinets; Prototype devices monitoring electrical parameters in LV cable cabinets; A prototype device allowing for steering and monitoring the operation of micro-generation installed in a customer s location; In the existing AMI infrastructure, new software has been used to enable obtaining additional data, both from meters installed in customers locations and meters installed in SSs. In the area of IT systems, the following systems have been implemented and tested: 5 167

6 Distribution Management System for LV network (DMS LV) a system supporting management of an LV network, Supervisory Control and Data Acquisition LV (SCADA LV), Field Crew Support (FCS), Extension of User Data Panel (UDP), web application for customers that provides data from smart meters. The studies and tests of the installed devices focused on an analysis aimed at verifying that they operate correctly and perform the expected functionalities. This was of key importance for defining the possibilities of using these solutions ultimately in the entire EOP network. The preparation and implementation of new devices (Remote Terminal Unit (RTU) integrated with Fault Passage Indicators, routers) showed a very high flexibility and readiness of the suppliers active on the Polish market. The prepared new (extended) requirements and the technical specification in the UPGRID project formed the basis for adjusting the existing solutions to the needs of the UPGRID project. This pertained in particular to new devices of Smart Secondary Substation (SSS). The developed new SSS solutions made it possible to: Reduce the costs of the installed infrastructure for monitoring and supervision in SSs (integration of AMI and network automation), Ensure monitoring in all the SSs and introduce varied monitoring levels, Implement new standards in the area of telecommunications and cybersecurity, Confirm readiness of the Polish market to respond quickly to DSOs needs and develop the products at their disposal. As a result of performed tests and studies of new SSS solutions, EOP decided to introduce a new SSS standard to be used over the entire network. It is based on the solutions first applied in the UPGRID demonstration area. The new technical standard has already been used since It is an improved solution originating from the UPGRID project. The new requirements in the project for the telecommunications area formed the basis for changes in EOP in this domain, especially in the area of cybersecurity. The implemented and tested IT system solutions have enabled the use of data obtained from smart meters in providing support to network management activities. A key challenge facing any DSO is to ensure a high quality of data about the network and to link these data with the locations in which smart meters have been installed. The UPGRID project, by preparing the implementation in the demonstration area, made it clear how much time is required to prepare data that will enable the creation of new functionalities in SCADA and DMS LV. The operation of the pertinent IT systems was verified by a series of tests. The tests have not brought about an end to work on enhancing the functionalities of the recently developed solutions. During the remaining term of the project, the effective operation of these functionalities will be tested. DMS LV and SCADA LV deployment have confirmed the use of smart meter data to support network operation

7 For the first time, functionalities were built using data from the PLC telecommunications layer. Algorithms analyzing communication problems with smart meters have been deployed and are being developed. Based on such analysis, potential places with a permanent loss of connectivity are identified locations of potential failures in the LV network. Data on such places are transmitted to SCADA LV and are visualized on maps depicting the LV network. It was of key significance for the project a tool that would enable the provision of direct support to customers. The newly developed solution provides customers with knowledge about potential PV installation opportunities and the effects that such installation will have on the individual electricity consumption by the customer. The project has implemented planned devices to increase network visibility. A small number of PV installations and no consent of the owners have limited the testing of Low Voltage Monitoring and Control (LVMC) units to one location. The planned IT system functionalities were implemented and functional tests were performed. In the field of test and evaluation algorithms are required further study

8 TABLE OF CONTENTS 1 INTRODUCTION BACKGROUND UPGRID POLISH DEMONSTRATOR SCOPE OF THE DOCUMENT 22 2 DEPLOYMENT OF POLISH DEMONSTRATOR THE NEWLY DEVELOPED FIELD DEVICES SMART SECONDARY SUBSTATION LV NETWORK MONITORING AND CONTROL DEVICES LVMC PLC BASED CONTROLLERS DATA CONCENTRATORS AND ELECTRICITY METERS THE INFORMATION SYSTEM DISTRIBUTION MANAGEMENT SYSTEM FOR LV (DMS LV) USER DATA PANEL (UDP) FIELD CREW SUPPORT (FCS) SCADA MV/LV 51 3 FUNCTIONAL TESTS OF THE NEWLY DEVELOPED FIELD DEVICES FUNCTIONAL TESTS OF THE NEWLY DEVELOPED FIELD DEVICES SMART SECONDARY SUBSTATION DEVICES EVALUATION OF TEST RESULTS LV NETWORK MONITORING DEVICES LOW VOLTAGE SUBSTATIONS EQUIPPED WITH FAULT CURRENT DETECTION DEVICES OBJECT TESTS OF SMART GRID DEVICES SITE ACCEPTANCE TESTS REQUIRED EQUIPMENT AND INSTRUMENTATION PREPARATION FOR THE TESTS TESTING PROCEDURE TEST RESULTS EVALUATION OF TEST RESULTS DER MONITORING AND CONTROL (LVMC) DEVICES DESCRIPTION OF TEST PROCEDURES

9 3.3.2 TEST RESULTS EVALUATION OF TEST RESULTS 82 4 FUNCTIONAL TESTS OF THE SOFTWARE FUNCTIONALITIES DMS LV TESTS DMS1 - SECONDARY SUBSTATION MONITORING - DISPLAY OF MEASURED VALUES DMS2 - SECONDARY SUBSTATION MONITORING - VIEW ON THE MAP DMS3 - DISPLAY THE LIST OF DER DMS4 - CALCULATION OF TRANSFORMER LOSSES IN THE OPTIMIZATION MODULE DMS5 - CALCULATIONS OF SAIDI AND SAIFI DMS6 - CALCULATIONS OF SAIDI AND SAIFI CUT-OFF TEST DMS7 - FAILURE DETECTION BASED ON PLC DMS8 - FAILURE DETECTION BASED ON PLC TRANSMISSION OF INFORMATION TO SCADA DMS9 DMS15 MONITORING OF SECONDARY SUBSTATIONS ALARMS DMS16 FLOW CALCULATIONS TRANSMISSION OF INFORMATION TO SCADA DMS18 ISOLATION OF NETWORK ELEMENTS IN THE EVENT OF A FAILURE DMS19 RECEIVING OBJECT STATUSES FROM SCADA DMS20 SELECTION OF THE OPTIMAL TRANSFORMER DMS21 GENERATION OF A REPORT ON THE POSSIBILITY OF TRANSFORMER OPTIMIZATION IN THE SECONDARY SUBSTATION DMS22 PRESENTATION OF THE LOG OF EVENTS FOR A SECONDARY SUBSTATION DMS23 MONITORING OF SECONDARY SUBSTATIONS LOSSES ON LINE SECTIONS DMS24 SAIDI AND SAIFI REPORT GENERATION DMS25 PRESENTATION OF BACKGROUND MAPS DMS26 PRESENTATION OF SELECTED ENGINEERING CALCULATIONS DMS27 PRESENTATION OF THE LIST OF TRANSFORMERS DMS LV - EVALUATION OF TEST RESULTS UDP1 - SIMULATION OF PV GENERATION UDP - EVALUATION OF TEST RESULTS FIELD CREW SUPPORT (FCS) TESTS FCS1 - MAP VIEW FCS2 - FINDING OBJECTS FCS3 FCS 6 - DISPLAYING OBJECT PARAMETERS FCS7 TRANSMISSIONS OF PHOTOGRAPHS TO SCADA LV FCS - EVALUATION OF TEST RESULTS

10 4.4 SCADA LV DER MANAGEMENT LV NETWORK TOPOLOGY MANAGEMENT FDIR FOR LV NETWORK SCADA TELECOMMUNICATION LAYER EVALUATION OF TEST RESULTS INTEGRATION BETWEEN COMPONENTS AND EXTERNAL SYSTEMS - MODEL VALIDATION ALGORITHMS FOR REALIZATION OF DMS LV FUNCTIONS CALCULATING POWER DISTRIBUTION FORECASTING LOADS AND DISTRIBUTED GENERATION FORECASTING TRANSFORMER TEMPERATURE CONCLUSIONS SMART SECONDARY SUBSTATIONS NEW FUNCTIONALITY OF IT SYSTEMS QUALITY OF DATA AND DATA MANAGEMENT 165 REFERENCES

11 LIST OF FIGURES FIGURE 1: GRAPHICAL LOCATION OF THE UPGRID POLISH DEMONSTRATOR IN GDYNIA 21 FIGURE 2: SAMPLE AMI/SG CABINET, VERSION 1W, A SOLUTION USED IN AN EXISTING SUBSTATION WITH LV SWITCHGEAR WITHOUT THE POSSIBILITY OF CONTROLLING 28 FIGURE 3: SAMPLE AMI/SG CABINET, VERSION 2W, A SOLUTION USED IN SUBSTATIONS WITH LV SWITCHGEAR WITH THE POSSIBILITY OF CONTROLLING 28 FIGURE 4: REMOTE TERMINAL UNIT AND FAULT PASSAGE INDICATOR (RTU+ FPI) 29 FIGURE 5: THE DIAGRAM OF LV NETWORK WITH MONITORING IN CABLE CABINETS (CABLE CABINETS WITH MONITORING BLUE COLOUR) 33 FIGURE 6: CABLE CABINET MONITORING DEVICE 34 FIGURE 7: LOW VOLTAGE MONITORING AND CONTROL DEVICE STANDALONE AND WITH PV INVERTER 36 FIGURE 8: POLISH DEMO HIGH-LEVEL SYSTEM DESIGN 40 FIGURE 9: UPGRID SYSTEM ARCHITECTURE 41 FIGURE 10: DMS LV INTERFACE BASED ON SOLUTIONS FROM AMI 44 FIGURE 11: PARAMETER VIEW (POL. PARAMETRY) 45 FIGURE 12: MEASUREMENTS VIEW (POL. POMIARY) 46 FIGURE 13: TOPOLOGY VIEW (POL. TOPOLOGIA 47 FIGURE 14: EVENT LOG VIEW (POL. ZDARZENIA) 47 FIGURE 15: TRANSFORMER OPTIMIZATION RESULTS 48 FIGURE 16: PV SIMULATION PANEL (MONTHLY SIMULATION) 49 FIGURE 17: PV SIMULATION PANEL (DAILY SIMULATION) 49 FIGURE 18: FCS - MAP VIEW 50 FIGURE 19: FCS - TABLE VIEW 50 FIGURE 20: FCS - SECONDARY SUBSTATION PROPERTIES 51 FIGURE 21: FCS - NODES AND METERING POINTS 51 FIGURE 22: SCADA LV SYSTEM ARCHITECTURE 52 FIGURE 23: SCADA- LV NETWORK ON THE MAP VIEW 53 FIGURE 24: SCADA- LV NETWORK SCHEMA VIEW

12 FIGURE 25: SCADA- CIM MODEL VISUALISATION 54 FIGURE 26: SCADA LV WITH A VIEW OF THE EVENT LOG 55 FIGURE 27: SCADA- LV CABLE CABINET WITH MONITORING 55 FIGURE 28 DATA CONCENTRATOR LOGIN SCREEN 77 FIGURE 29: DATA CONCENTRATOR TOPOLOGY DEVICE SELECTION 77 FIGURE 30: DATA CONCENTRATOR CLOCK COMMANDS 77 FIGURE 31: DATA CONCENTRATOR QUERY FOR A- REGISTER 78 FIGURE 32: DATA CONCENTRATOR SECURITY TOKEN INPUT 78 FIGURE 33: DATA CONCENTRATOR RESPONSE TO QUERY FOR A- REGISTER 78 FIGURE 34: DATA CONCENTRATOR DISCONNECTOR STATUS 79 FIGURE 35: DATA CONCENTRATOR DISCONNECTOR CONTROL 79 FIGURE 36: DATA CONCENTRATOR DISCONNECTOR CONTROL 80 FIGURE 37: DATA CONCENTRATOR AVAILABLE DEVICE PROFILES 80 FIGURE 38: DATA CONCENTRATOR QUERY FOR INSTANTANEOUS P- REGISTER 81 FIGURE 39: DATA CONCENTRATOR RESPONSE TO QUERY FOR INSTANTANEOUS P- REGISTER 81 FIGURE 40: VIEW MAPS IN DMS LV 90 FIGURE 41: DMS LV LIST OF CUSTOMERS WITH A DER 91 FIGURE 42: VIEW OF RECEIVED FAILURE MESSAGES IN SCADA 98 FIGURE 43: SCADA-LV, DISPLAY OF ALARMS 100 FIGURE 44: DMS LV, MEASUREMENTS TAB 100 FIGURE 45: SCADA- PRESENTATION OF MEASUREMENT DATA 101 FIGURE 46: SCADA- PRESENTATION OF MEASUREMENT DATA IN NODES 102 FIGURE 47: DMS LV CHART OF LOSSES IN LINE SEGMENTS 106 FIGURE 48: MAP VIEW ALARMS WITH EXCEEDED THDUS DISPLAYED 108 FIGURE 49: DMS LV LIST OF TRANSFORMERS 109 FIGURE 50: UDP VIEW OF SIMULATED ELECTRICITY GENERATION ON AN ANNUAL BASIS 111 FIGURE 51: UDP VIEW OF SIMULATED ELECTRICITY GENERATION AFTER CHANGING THE TIME RANGE112 FIGURE 52: FCS - MAP VIEW 113 FIGURE 53: FCS - LIST VIEW 114 FIGURE 54: FCS - SS DETAILS

13 FIGURE 55: SCADA LV - COMMAND TURN OFF DER 118 FIGURE 56: SCADA LV - VISUALIZATION OF DER SHUTDOWN 119 FIGURE 57: SCADA LV - COMMAND TURN ON DER 120 FIGURE 58: SCADA LV - VISUALIZATION OF DER ACTIVATION 121 FIGURE 59: INFORMATION TRANSMITTED FROM A DER TO SCADA LV 122 FIGURE 60: VISUALIZE THE NETWORK IN THE DMS LV AND SCADA LV BEFORE CHANGING THE CONNECTION 123 FIGURE 61: VISUALIZE THE NETWORK IN THE DMS LV AND SCADA LV AFTER CHANGING THE CONNECTION 124 FIGURE 62: VIEW OF SS IN DMS LV 125 FIGURE 63: VIEW OF SS IN SCADA LV 125 FIGURE 64: LV CABLE CABINET WITH ACTIVE FPI 127 FIGURE 65: VIEW OF THE TRANSMITTED PLAN IN SCADA LV 128 FIGURE 66: VIEW OF CONNECTOR STATUS CHANGE 129 FIGURE 67: VIEW OF SEQUENCE SIMULATION 130 FIGURE 68: VIEW OF SEQUENCE OF SWITCHINGS IN SCADA LV 131 FIGURE 69: TELECOMMUNICATION LAYER SCHEME FOR UPGRID PROJECT TESTING 133 FIGURE 70: CIM RDF XML FILE VALIDATION RESULT. 137 FIGURE 71: CIMPHONY WORKSPACE WITH VALIDATED CIM RDF XLS INPUT FILE OBJECT BROWSER. 138 FIGURE 72: CIMPHONY WORKSPACE WITH VALIDATED CIM RDF XLS INPUT FILE TEXT BROWSER 138 FIGURE 73: LV GRID SUPPLY FROM MITROWA SUBSTATION. REFERENCE MODEL 140 FIGURE 74: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO 15 MIN 150 FIGURE 75: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO 1 H 150 FIGURE 76: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO 6 H 150 FIGURE 77: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO FIGURE 78: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO 24 H

14 FIGURE 79: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO 48 H 151 FIGURE 80: LINE SECTION CURRENTS DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 15 MIN. MITROWA SECONDARY SUBSTATION 152 FIGURE 81: LINE SECTION CURRENTS DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 1 H. MITROWA SECONDARY SUBSTATION 152 FIGURE 82: LINE SECTION CURRENTS DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 6 H. MITROWA SECONDARY SUBSTATION 152 FIGURE 83: LINE SECTION CURRENTS DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 12 H. MITROWA SECONDARY SUBSTATION 153 FIGURE 84: LINE SECTION CURRENTS DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 24 H. MITROWA SECONDARY SUBSTATION 153 FIGURE 85: VOLTAGES (A) AND CURRENTS (B) DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 15 MIN. WITOMINO AREA 154 FIGURE 86: VOLTAGES (A) AND CURRENTS (B) DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 1 H. WITOMINO AREA 154 FIGURE 87: VOLTAGES (A) AND CURRENTS (B) DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 6 H. WITOMINO AREA 154 FIGURE 88: VOLTAGES (A) AND CURRENTS (B) DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 12 H. WITOMINO AREA 155 FIGURE 89: VOLTAGES (A) AND CURRENTS (B) DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 24 H. WITOMINO AREA 155 FIGURE 90: NUMBER OF METERS THAT REPLY IN ASSUMED TIME. MITROWA SUBSTATION 156 FIGURE 91: DIFFERENCE BETWEEN CALCULATED VALUE AND MEAN VALUE CALCULATED FROM MEASURED VOLTAGES (A), AND MEASUREMENTS NUMBER IN VDEV FUNCTION (B) 159 FIGURE 92: DIFFERENCE BETWEEN ESTIMATED AND REAL VALUES. LIMITED TO 1000% (A) AND 100% (B). ESTIMATION WITH 7 MEASUREMENT DAYS 160 FIGURE 93: METERS NUMBER FOR WHICH DIFFERENCE BETWEEN ESTIMATED AND REAL VALUES LOCATES IN ASSUMED RANGE. ESTIMATION WITH 7 MEASUREMENT DAYS 160 FIGURE 94: DIFFERENCE BETWEEN ESTIMATED AND REAL VALUES. LIMITED TO 1000% (A) AND 100% (B). ESTIMATION WITH 10 MEASUREMENT DAYS 161 FIGURE 95: METERS NUMBER FOR WHICH DIFFERENCE BETWEEN ESTIMATED AND REAL VALUES LOCATED IN ASSUMED RANGE. ESTIMATION WITH 10 MEASUREMENT DAYS 161 FIGURE 96: SCADA LV MAP VIEW WITH ALARMS (INFORMATION ABOUT PROBABILITY OF FAILURE IN LV NETWORK)

15 LIST OF TABLES TABLE 1 SUPPORT AREAS IN THE POLISH DEMO UPGRID 24 TABLE 2 FUNCTIONALITIES OF INTEGRATED AMI/SG CABINETS 27 TABLE 3 LIST OF SECONDARY SUBSTATIONS TOGETHER WITH INFORMATION ABOUT THE EQUIPMENT INSTALLED IN THEM 30 TABLE 4: DETAILED INFORMATION ABOUT THE SCOPE OF MONITORING IN INDIVIDUAL MEASUREMENT CABINETS 35 TABLE 5: PARAMETRIZATION CHANGE FOR 1-PHASE CUSTOMER METER 37 TABLE 6: PARAMETRIZATION CHANGE FOR 3-PHASE CUSTOMER METER 37 TABLE 7: PARAMETRIZATION CHANGE FOR 3-PHASE CUSTOMER METER 38 TABLE 8: MODULES OF DMS 42 TABLE 9: LIST OF MV SECONDARY SUBSTATIONS WITH SG DEVICES AND PERFORMED SG FUNCTIONS _ 56 TABLE 10: SPECIFICATIONS OF SITE ACCEPTANCE TESTS PERFORMED IN EACH MV SUBSTATION 62 TABLE 11: RESULTS OF SITE ACCEPTANCE TESTS PERFORMED IN EACH SECONDARY SUBSTATIONS 69 TABLE 12: LIST OF LOW VOLTAGE CABLE CABINETS WITH FAULT CURRENT DETECTION DEVICES 73 TABLE 13: RESULTS OF LVMC TEST 81 TABLE 14 VOLTAGE OF NODES. LV GRID SUPPLY FROM MITROWA SECONDARY SUBSTATION 141 TABLE 15 LINE SECTION CURRENT. LV GRID SUPPLY FROM MITROWA SECONDARY SUBSTATION 142 ABLE 16 ACTIVE POWER LOSSES IN LINE SECTIONS. LV GRID SUPPLY FROM MITROWA SECONDARY SUBSTATION 143 TABLE 17 SUM OF ACTIVE POWER LOSSES. LV GRID SUPPLY FROM MITROWA SUBSTATION 144 TABLE 18 VOLATGE OF NODE. LV GRID SUPPLY FROM MITROWA SECONDARY SUBSTATION 144 TABLE 19 LINE SECTION CURRENT. LV GRID SUPPLY FROM MITROWA SECONDARY SUBSTATION 147 TABLE 20 TIME OF POWER FLOW FUNCTION EXECUTION 157 TABLE 21 NODE VOLTAGE. WITOMINO AREA. MEASUREMENT DATA AVAILABLE UP TO 1 H

16 ABBREVIATIONS AND ACRONYMS AIES AMI AP APN CDB CIM COSEM DER DLMS DMS DMS LV DNP DSO EDGE EOP FCS FDIR FPI GIS GPRS GPS GSM GUI Name of Network Management System used in ENERGA Advanced Metering Infrastructure Access Point Access Point Name Central Data Base Common Information Model Companion Specification for Energy Metering Distributed Energy Resource Device Language Message Specification Distribution Management System DMS for LV network Distributed Network Protocol Distribution System Operator Enhanced Data GSM Environment ENERGA OPERATOR SA Field Crew Support Fault detection, isolation and restoration system Fault Passage Indicator Geographic Information System General Packet Radio Service Global Positioning System Global System for Mobile communications Graphical User Interface

17 HV IPsec IT ICT LAN LV LVMC MDG MDM MV NA NCM OMS PKI PLC PP PPE PRIME PV SAIDI SAIFI SAT SCADA SCP SF6 SG SNMP High Voltage Internet Protocol security Information Technology Information and Communication Technology Local Area Network Low Voltage Low Voltage Monitoring and Control Meter Data Gateway Meter Data Management Medium Voltage Network Analysis Network Control and Management Outage Management System Performance Key Indicators Power Line Communication Metering Point Power Delivery Point PoweRline Intelligent Metering Evolution Photovoltaic System Average Interruption Duration Index System Average Interruption Frequency Index Site Acceptance Test Supervisory Control and Data Acquisition Secure Copy Protocol Sulfur hexafluoride Smart Grid Simple Network Management Protocol

18 SS SSH SSS STGP THD THDU UDP UMTS VPN WP6 WWW ZKB Secondary Substation Secure Shell (protocol) Smart Secondary Substations SSH File Transfer Protocol Total Harmonic Distortion Total Harmonic Distortion of the voltage waveform User Data Panel Universal Mobile Telecommunications System Virtual Private Network Work Package 6, demonstrations in real user environment (Poland) World Wide Web Integrated device: AMI concentrator and meter installed in SSs

19 1 INTRODUCTION The energy sector is constantly affected by technological and business trends, as a result of which it undergoes an increasingly faster and deeper transformation. What play an ever more important role in shaping the energy market are environmental and climatic conditions, and this fact influences directly into legal regulations in the EU and in Poland. A sharp increase is also observed in the area of the use of solutions based on information and communication technologies. A rapid evolution of the Internet, telecommunications and digitization provides end users with tools enabling them to assume new roles in the area of generation and optimization of energy use. Changes taking place on the energy market and the development of technologies and new challenges created as a result of those changes significantly affect the scope of Work Package 6 (WP6) the Polish demonstration area in the UPGRID project. The technological progress made possible to use new solutions tools which will support the business of Distribution System Operators (DSOs) and to create new opportunities for customers. 1.1 BACKGROUND The implementation of innovative solutions in the Smart Grid area is one of the ways of rising up to the new challenges faced by Distribution System Operators (DSOs). The selection and effective implementation of specific smart grid technologies requires an in-depth analysis of expected costs and benefits possible to achieve. Smart grid technologies should support and supplement traditional methods of grid development. This will mean large-scale implementation of smart grid solutions, which will eventually lead to a power system that: will utilize more optimally its infrastructures, will be predicting, not just reacting to emergencies arising, will be self-healing and adaptive, will be distributed independently of geographic or organizational limits, integrated, combining a variety of systems. DSO will have to meet these previously mentioned challenges and expectations. Both ENERGA-OPERATOR SA and other operators of distribution networks are currently facing a number of challenges. Each of them involves the need to take up certain actions: improvement of the reliability and security of energy supply and ensuring high- -quality energy, optimization of the use of existing infrastructure and organizational resources, improvement of the efficiency of distributing power grid, creation of opportunities for increasing customer s active role in energy consumption management and energy generation,

20 integration of distributed sources and balancing the system in terms of increasing the participation of distributed and disseminated generation, preparation of technical and organizational solutions to engage DSO in system balancing on distribution network level, improvement of the accuracy of forecasting the generation from distributed sources, preparing the system for the implementation of electric cars on a massive scale. Facing to a substantial part of those challenges can occur through the implementation of new innovative solutions in the area of smart grids. ENERGA OPERATOR SA has been executing pilot projects for several years to study smart grid technologies. These studies have enabled the implementation of new solutions in the operational area. The development works that have been conducted to date have focused on technologies applied in High Voltage (HV) and Medium Voltage (MV) grids. In these voltage ranges, two systems were developed: the Supervisory Control and Data Acquisition (SCADA) system and the Distribution Management System (DMS); also, devices for supervising and monitoring the network were installed. Systems were also developed to enable the monitoring of dispersed generation. An important element developed at ENERGA-OPERATOR SA was the Advanced Metering Infrastructure (AMI). At present, nearly 800,000 municipal customers are equipped with smart meters. The system focuses on the delivery of measurement data to billing systems and providing customers with information on their electricity consumption. To date, smart grid pilot projects have not covered Low Voltage (LV) network. Currently, this grid is neither monitored nor supervised. The key Information Technology (IT) tool in the grid area is the Geographic Information System (GIS). In the GIS, information is collected about each element of LV grids. Because of the large volume of the GIS data, their quality needs to be verified with respect to the objectives supporting network operation. On the other hand, there is a rapid increase in the number of micro-generation systems installed by domestic customers, especially Photovoltaic (PV) units. Another important factor contributing to changes in LV grid management will be an increase in the number of electric cars. The Polish government s plans for the development of the electric transport sector will also support its quick growth. Challenges resulting from the development of the energy market require the creation of methods for managing the LV grid. For this reason, in the Polish demonstration area, a particular emphasis was placed on improving the observability of the LV grid using currently available data (e.g. AMI, GIS) and newly installed prototype monitoring devices. 1.2 UPGRID POLISH DEMONSTRATOR The scope of the implemented innovative solutions in the Polish demonstration area follows directly from the changes occurring on the energy market and the role played by DSOs. The objectives in the

21 Polish demonstration area result for the most part from challenges associated with changes occurring in the area of LV grids and from the needs for better customer support. The main technical objectives that the demonstrator envisages are: Utilization of the LV network for communication devoted for transferring data other than metering, Implementation of SCADA MV/LV and DMS for LV network (DMS LV) with micro generation control, The use of Common Information Model (CIM) standards and integration date of SCADA and DMS, The use of AMI system for monitoring the performance of LV power grid. The project objectives are pursued by implementing new solutions in the following two areas: Increasing the level of network monitoring by taking advantage of the existing AMI infrastructure and new devices for network monitoring, Building an IT system using, among others, data from network monitoring. The Polish demonstration area (Polish Demo UPGRID) is located in Gdynia City in the area of 3 districts: Witomino, Dzialki Lesne as well as Chwarzno. It includes 55 SSs which supply nearly 15,000 customers. The MV network consists exclusively of underground cable lines with a total length of 34 km. The LV network includes both, underground cable and overhead lines with a total length of 100 km. The UPGRID project in the Polish demonstration area focuses on monitoring and control of LV network by the utilization of the data obtained from the smart metering infrastructure and introducing the control processes that are currently used for the MV network into the LV network. The area of demonstration is presented in the Figure 1. FIGURE 1: GRAPHICAL LOCATION OF THE UPGRID POLISH DEMONSTRATOR IN GDYNIA The Polish demonstration area existing within the framework of WP6 is being created by a consortium composed of the following entities: ENERGA-OPERATOR SA. As a DSO, it plays the role of the leader of the Polish demonstration area executed within WP6. ENERGA-OPERATOR runs its business in a territory covering 24% of Poland and

22 delivers electricity to nearly 3 million customers. It is a leader in implementing innovative technologies among the DSOs operating in Poland. Gdańsk University of Technology. A university with a great tradition, established in It conducts research work and supports DSOs and other participants of the energy market in the development of technologies in the areas of electricity generation, distribution and transmission. In WP6, it is responsible for preparing and testing algorithms implemented in the IT system. The Institute of Power Engineering is a research institute conducting scientific studies and implementation works in the following areas: forecasting and planning the development of power engineering, generation, transmission, distribution and use of electricity, heat and unconventional energy sources. Atende and Atende Software Sp. z o.o. Atende is the holder of a 100% stake in Atende Software Sp. z o.o. Atende Software Sp. z o.o. is a technological partner of ENERGA-OPERATOR SA in the implementation of the AMI system. Another company that participated in the works is Mikronika. Mikronika is the supplier of SCADA solutions used in the demonstration area. The company is a Polish leader among the suppliers of SCADA/DMS systems and devices for monitoring and supervising power grids. 1.3 SCOPE OF THE DOCUMENT Based on the tasks from T6.1 to T6.4, the Polish demonstration area has been built as planned in the project. New prototype solutions in the grid area as well as new IT solutions have been implemented. The purpose of this document is to sum up the results of the work done in the Polish demonstration area and the completed tests. The tests and studies were aimed at verifying that the performed work had been consistent with the project objective. They were also intended to help create a presentation of recommendations about the possibility of implementing the solutions in the network of DSOs. Chapter 1 of the final report contains a description of key information introducing the topic of the Polish demonstration area created under the UPGRID project. In chapter 2, the implemented solutions are presented. Both the description of the applied prototype devices in the network and the description of the implemented IT system were written so as to present the key information forming the basis for the description of the tests. The tests are described in the following two chapters. In chapter 3, tests of the devices designed for monitoring and supervising the network are described. Chapter 4 presents the results of tests performed on the IT system. Chapter 5 sums up the completed works and performed tests in the Polish demonstration area

23 2 DEPLOYMENT OF POLISH DEMONSTRATOR To meet the present and future requirements facing the DSOs, very important areas to be developed are MV and LV grids. The development is supported by smart grid technologies. Particularly significant elements in the grids are the Secondary Substations (SS). These SSs provide key data to support management of MV and LV grids. The development of smart grid technologies in the area of LV grids is also of importance to customers as opportunities for their active participation in the energy market. The smart meters are a valuable source of data that is not fully exploited. The integration of the data obtained from monitoring MV and LV grids and the data from smart meters present a very important challenge with regard to raising the quality of electricity supplies, improvement of effectiveness of network management and, above all, providing new opportunities for energy management by customers. Innovative works are performed in this area in the Polish UPGRID demonstration area. The Polish demonstration area (WP6) is executed in five tasks: T6.1 System Analysis, T6.2 System Design, T6.3 Network infrastructure deployment, T6.4 ITC solutions deployment, T6.5 Systems testing and optimization. Within the first task, T6.1 System Analysis, the needs and possibilities for implementing innovative solutions in the MV and LV grids have been analysed. Based on the analysis, major objectives to be achieved in WP6 have been specified in detail. Methods for achieving the objectives have been defined, i.e. solutions planned for implementation regarding new devices installed in the network and the IT system for supporting LV grid management. The technical objectives of the Polish Demo include the mapping of the LV network status in the IT system, together with power quality parameters and better controllability of the LV network, and the development of advanced IT tools which, in practice, will demonstrate the possibilities of: integration of the SCADA/DMS LV, GIS, AMI systems using the CIM standard, increased LV network observability and improved LV network management, improved reliability of LV networks, improved management of distributed generation (microgeneration) in the LV network. The assumed benefits achieved in the Polish Demo will include: increased reliability of the distribution network in the demonstration area through significantly increase of the observability and controllability of the network and of the elements connected to it; increased hosting capacity and flexibility to ensure integration of microgeneration in LV networks; verification of the feasibility to use selected solutions and technical standards in the integration and control of the distribution networks in accordance with the results of the demonstration project

24 The selected support areas in the Polish Demo are shown in Table 1. These areas result from the list of sub-functionalities which have been classified based on the Clusters and Function Objectives using the EEGI roadmap TABLE 1 SUPPORT AREAS IN THE POLISH DEMO UPGRID Cluster & Function Objectives Integration of Distributed Energy Resource (DER) and new uses D3 Integration of DER at low voltage Network operations D7 Monitoring and control of LV networks D8 D9 Automation and control of MV networks only in the scope of fault detectors testing Network management methodologies for network operation D10 Smart metering data utilization Network planning and asset management D11 Novel planning approaches for distribution networks D12 Novel approaches to asset management Market design D13 New approaches for market design In the next task, T6.2 System Design, draft solutions planned for application have been prepared. These draft solutions included:

25 Devices installed in the demonstration area (new solutions for monitoring MV and LV grids), Software (SCADA LV, DMS LV, FCS, existing UDP extension). Within task T6.3 Network infrastructure deployment, the devices designed in T6.2 have been deployed in the field. In document D6.3, the scope of the applied new solutions has been described in detail. The scope of the works performed in the project, including the IT system, has been completed in task T6.4 ITC solutions deployment. At the stage of implementing the IT system, the solutions designed in T6.2 were verified on an ongoing basis, introducing possible modifications. The modifications were aimed at increasing the effectiveness of the system. As part of the works performed in T6.4, the required changes and modifications of the solutions designed in D6.2 were introduced. A description of the target IT system is presented in document D6.4 [4]. This document constitutes a summary of the works completed in task T6.5 and includes results of the completed tests confirming that all the works planned in WP6 have been performed. It also includes preliminary conclusions. 2.1 THE NEWLY DEVELOPED FIELD DEVICES To increase the level of monitoring and supervision in the MV and LV grids, additional devices have been used in the demonstration area. They have been specially designed and built for the needs of the UPGRID project. Their implementation and the conducted tests aimed to verify opportunities for using them in urban power networks. The new solutions include: Prototype solutions for monitoring and supervising SSs integrated AMI/SG cabinets, Prototype devices monitoring electrical parameters in LV cable cabinets, A prototype device allowing for steering and monitoring the operation of micro-generation, In the existing AMI infrastructure, new software has been used to enable obtaining additional data, both from meters installed in customers locations and meters installed in SSs SMART SECONDARY SUBSTATION SSs are a key grid element which ensures that MV and LV grids are monitored and supervised. In the solutions used to date in the EOP network, two types of equipment have been installed in SSs (types 1W and 2W): AMI infrastructure. It included a cabinet containing a concentrator set integrated with a meter measuring electricity flowing through LV buses and a telecommunications modem. Electric current is measured by current transformers installed on LV switchgear buses. Data from the infrastructure are provided to the AMI/CBP application and utilized only for the purposes of the billing system. SSs automation infrastructure. At present, in over 10% of SSs remote-controlled MV switchgears are installed with the necessary equipment allowing for remote control. In selected fields, installed FPIs

26 are used. Monitoring and supervision were ensured by an RTU installed with a modem and an UPS in a separate cabinet. A telecommunications modem was used for communication. These devices were installed independently of the AMI infrastructure. The objective of the UPGRID project was to raise the level of monitoring and supervision in SSs by integrating the AMI devices with network automation. The integration aimed at increasing the economic effectiveness of the applied solutions. At the stage of task T6.1, the following was decided: Each of the urban SSs should ensure monitoring in selected fields of the MV and LV switchgears, In approx. 30% of SSs, remote connections should be provided on the MV side. Monitoring devices should ensure the detection of short-circuit currents and the measurement of operating currents, In selected stations, monitoring should be possible at each circuit of a LV switchgear, In the applied solutions, the objective should be to integrate devices. The designed cabinets are a key element of a SSS. Within the project, new SSS solutions were designed and implemented integrated AMI/SG cabinets. Based on the technical documentation prepared for the UPGRID project, solutions were purchased from three different vendors. This enabled the verification of the possibility to acquire such solutions on the market. The solutions prepared by the three vendors confirmed that the polish market is ready for producing new solutions for the needs of DSOs. The tests performed in task T6.5 and described in this document (chapter 3 Functional tests of the newly developed field device ) were to verify the new product and effectiveness of its operation. In new cabinets, integrated solutions of AMI devices and MV network automation were used. The technical specification on the basis of which the cabinets were made included two types of cabinets: 1W and 2W. The implemented solutions involved two levels of monitoring and controlling SSSs. The solutions were prepared in such a manner that they could be used for various types of SSs which are used at present in the DSO network. The solutions made it possible to be used both in new SSs and in those already operated within the network. Table 2 presents key functionalities of the solutions. Sample 1W and 2W cabinets used in the project are shown in Figure 2 and Figure

27 TABLE 2 FUNCTIONALITIES OF INTEGRATED AMI/SG CABINETS 1W 2W Control of connectors Possible control of MV connectors in the switchgear Monitoring the operation of the MV/LV grid 1. Detection of line-to-earth faults in the MV network 2. Current measurement in the network 3. Information about an LV fuse link burn-out* 4. Indication of the opening of disconnector in the MV field of the transformer 5. Signaling the opening of substation and cabinet door 6. Indication of zero outage (MV, LV) 1. Detection of line-to-earth faults in the MV network 2. Current measurement in the network 3. Information about an LV fuse link burn-out 4. Indication of the opening of disconnector in the MV field of the transformer 5. Indication of the opening of disconnector in the line field of the MV switchgear 6. Signaling the opening of substation and cabinet door 7. Indication of zero outage (MV, LV) Energy quality monitoring 1. Information about power supply outage in the MV/LV substation 2. Voltage in the substation 3. THD value for MV/LV substations 1. Information about power supply outage in the MV/LV substation 2. Voltage in the substation 3. THD value for MV/LV substations AMI 1. Acquisition of measurement data from customers meters 2. Information on alerts 3. Information about PLC topology 1. Acquisition of measurement data from customers meters 2. Information on alerts 3. Information about PLC topology Communications modem 1. Provision of data and information to the AMI and SCADA systems 2. Two independent communication channels used to transmit data 3. Assigning priority to signal transmission to the SCADA system 1. Provision of data and information to the AMI and SCADA systems 2. Two independent communication channels used to transmit data 3. Assigning priority to signal transmission to the SCADA system Power supply Backup power supply for 1 h to send necessary data about the detection of a failure Backup power supply for at least 24 h to ensure the possibility of controlling MV connectors

28 FIGURE 2: SAMPLE AMI/SG CABINET, VERSION 1W, A SOLUTION USED IN AN EXISTING SUBSTATION WITH LV SWITCHGEAR WITHOUT THE POSSIBILITY OF CONTROLLING FIGURE 3: SAMPLE AMI/SG CABINET, VERSION 2W, A SOLUTION USED IN SUBSTATIONS WITH LV SWITCHGEAR WITH THE POSSIBILITY OF CONTROLLING

29 The basic elements of the integrated AMI/SG cabinets include: Integrated device: AMI concentrator and meter installed in SSs (ZKB). SS is an element of the AMI infrastructure. The device is made up of a concentrator and meter measuring electrical parameters on the main buses of a LV switchgear. Integrated device: Remote Terminal Unit and Fault Passage Indicator (RTU+ FPI). In the UPGRID project, an RTU integrated with a FPI has been used. In contrast to the solutions used so far (separate RTU and FPI devices), the new solution ensures the possibility of bi-directional communication with FPI (e.g. remote software change or setting). The project has used solutions of three companies operating on the Polish market: Mikronika, the Institute of Power Engineering, Gdańsk Division and Wago. In Figure 4, photographs of the applied solutions are shown. A B C FIGURE 4: REMOTE TERMINAL UNIT AND FAULT PASSAGE INDICATOR (RTU+ FPI) A) RTU FIRMY MIKRONIKA (RTU INTEGRATED WITH ONE FPI); B) RTU FIRMY IENG (RTU INTEGRATED WITH TWO FPIS FPI); C) RTU FIRMY WAGO (RTU INTEGRATED WITH ONE FPI) Power supply system. Power supply system equipped with batteries allowing for backup supply for the cabinet, Router a common router has been used for AMI and for monitoring and controlling the substation. Both ZKB and RTUs transmit data to IT systems via the router. Table 3 presents a list of SSs where smart grid devices have been installed and indicates key functions performed by these devices

30 TABLE 3 LIST OF SECONDARY SUBSTATIONS TOGETHER WITH INFORMATION ABOUT THE EQUIPMENT INSTALLED IN THEM No. SS number Name of SS Type of MV switchgear Number of low voltage feeders Remote controlled MV switch Nominal power of transformer Number of customers Cmentarz RM kva Szczecińska Rue kva Pomorska Rue kva Tatrzańska IIDI kva Wolności Szkoła Rue kva Wolności DOMONT NE-IDI kva Tatrzańska Klasztor Rue kva Wolności RUe kva Nowogrodzka CTC-V kva Stawna RUe kva Jasna IIDI kva Witomino Radiostacja RM6 IDI kva Rolnicza RUe kva Narcyzowa RUe kva Zjazdowa Rue kva Wąska RUe kva Pasieczna RUe kva Mirtowa RUe kva Rozmarynowa RUe kva WielkoKacka II RM6 NE- IIDI kva Stawna I RUe kva Chwarznieńska WLLL kva Niska CA RUe kva

31 No. SS number Name of SS Type of MV switchgear Number of low voltage feeders Remote controlled MV switch Nominal power of transformer Number of customers Pionierów RUe kva Promienna RUe kva Hodowlana I RUe kva Profesorska RUe kva Nauczycielska RUe kva Sosnowa RUe kva Słoneczna RUe kva Konwaliowa I RUe kva Konwaliowa II RUe kva Małokacka RUe kva Narcyzowa I RUe kva Narcyzowa II RUe kva Cicha RUe kva Graniczna RUe kva Witomino Hydrofornia RUe kva Zielna Rue kva Łąkowa RUe kva Tulipanowa RUe kva Witawa RM6 DIDI, D, D kva Chwarzno Przepompownia Rue kva Chwarzno Apisa RUe kva Chwarzno Diany RUe kva Chwarzno Amona RUe kva Chwarzno Marsa RUe kva

32 No. SS number Name of SS Type of MV switchgear Number of low voltage feeders Remote controlled MV switch Nominal power of transformer Number of customers Chwarzno Zeusa IIDI kva Chwarzno Okrężna RUe kva Chwarzno Drukarnia Subscribers secondary substation OPWIK Warsztaty Subscribers secondary substation Pomorska WPWIK Subscribers secondary substation MIR Wolności Subscribers secondary substation Demptowska Las Subscribers secondary substation LV NETWORK MONITORING AND CONTROL DEVICES The demonstration area includes the urban LV grid. Mostly it is an underground cable network. A characteristic feature of the network is the possibility of switching and changing the grid operation system. It is a mesh-type grid with the possibility of changing division points between specific circuits and SSs. To increase the observability in each node, additional devices have been used to monitor selected cable cabinets. The existing cable cabinets have been replaced with new ones equipped with a monitoring module. In Figure 5 a circuit diagram is presented for a section of the LV grid with indicated installation places for new cable cabinets equipped with monitoring units. A sample solution is shown in Figure

33 FIGURE 5: THE DIAGRAM OF LV NETWORK WITH MONITORING IN CABLE CABINETS (CABLE CABINETS WITH MONITORING BLUE COLOUR)

34 FIGURE 6: CABLE CABINET MONITORING DEVICE In the selected LV network area, 9 previously selected cable cabinets have been replaced with new ones, equipped with STGP-3 monitoring systems in accordance with the prepared specification. Each of the cabinets has been equipped with new switch fuses which can be divided into two groups: switch fuses matching the underground cable cross sections and rated currents in the supply lines, connected to the cabinet (Imax=400A), and switch fuses for the lines supplying the off-takers from the given cabinet (Imax=160A). The value of the fuse link currents has been selected individually for each cabinet. In selected line bays, current transformers (400/5 Amper) have been installed for each of the 3 phases. Additionally, each of the cabinets is equipped with a system monitoring the work parameters of the given network, comprising: a STGP-3 control unit, 24V power supply with a battery set upholding the power supply, communication module and cable cabinet door opening signalling. The main task of the control unit is to send information to the dispatcher system regarding the measured values of the currents, voltages, active and reactive powers and signalling of the flow of short-circuit current in the selected bay. 6 cabinets have got monitoring of the flow of short-circuit currents in two linear outlets. 3 cabinets have monitoring of the flow of short-circuit currents in one circumventing feeder, due to the network work system and the location of the cabinet near the feeding station. STGP-3 controller with power supply system performs the following functions: remote signalling of fault current, local optical signalling of fault current,

35 remote door open signalling, automatic and remote (after time) reset of fault current signalling, remote signalling of the discharge of batteries, measurement of three or six phase currents (depending on the installation location) and three phase voltages with the remote transmission of measured values, remote signalling of the loss of phase voltage, fault detection algorithm: Threshold (time-independent) with separate current and time settings for ground faults (I0, t0) and line-to-line faults (I>, t>; I>>, t>>), recording and sharing waveforms of current at the time of fault, communication with SCADA system using Distributed Network Protocol (DNP) 3.0 protocol and General Packet Radio Service (GPRS) / Enhanced Data GSM Environment (EDGE) / Universal Mobile Telecommunications System (UMTS) packet data services, remote and local configuration through the World Wide Web (WWW) page, local and remote diagnostics (Global System for Mobile communications (GSM) / UMTS communication parameters, input states, measurement values, access to the event log) through the WWW page, local and remote access to Secure Shell (SSH) File Transfer Protocol (STGP)-3 controller configuration and diagnostics, remote and local ability to change STGP-3 controller software through the Secure Copy Protocol (SCP) protocol, the ability to encrypt communications using IPsec, and Open Virtual Private Network (Open VPN) protocols, supporting Simple Network Management Protocol (SNMP) protocol for access to diagnostic information about network interfaces. The table below (Table 4) presents detailed information about the scope of monitoring in individual measurement cabinets. No. TABLE 4: DETAILED INFORMATION ABOUT THE SCOPE OF MONITORING IN INDIVIDUAL MEASUREMENT CABINETS Name of cable cabinet Number of cable cabinet Secondary Substation Numbers of feeders Number of faults detectors 1 Malinka Z-4C/SKLEP/406 T Widna 3 kl.viii Z-3A/1021 T Widna 3 kl.ii Z-3B/1021 T Pogodna 2 kl.i Z-2A/402 T Widna 7A kl.i Z-7A/1021 T Widna 5 kl.i Z-5A/1021 T Pogodna 4 kl.iv Z-9D/1021 T Nauczycielska 8B Z-8/406 T Nauczycielska 16B Z-16/406 T

36 2.1.3 LVMC PLC BASED CONTROLLERS The purpose of the LVMC device is to monitor and control the operation of PV inverters. The device communicates with the AMI central system based on the Power Line Communication (PLC) PoweRline Intelligent Metering Evolution (PRIME) network. The device operates as a typical PLC PRIME node, registers on the data concentrator and may function both as a switch node and as a terminal node. The LVMC was designed and implemented specifically for the UPGRID project. The device vendor is the Institute of Power Engineering and was installed by the EOP. Due to lack of consent of the PV owners, the installation of the device has been limited to one location. The LVMC device connects with the PV inverter through RS485 serial interface. In the application layer, the LVMC device supports Device Language Message Specification (DLMS) protocol. The data model of the LVMC device uses Companion Specification for Energy Metering (COSEM) objects modelled on the basis of Blue Book specification, version 12. In the device, a set of objects has been implemented to perform in a comprehensive manner a number of functions connected with monitoring and controlling the operation of PV inverters. Figure 7 shows LVMC devices and PV inverter. FIGURE 7: LOW VOLTAGE MONITORING AND CONTROL DEVICE STANDALONE AND WITH PV INVERTER DATA CONCENTRATORS AND ELECTRICITY METERS In the demonstration area, the existing AMI infrastructure has been used. To increase the level of monitoring and ensure additional data to the implemented AMI/DMS system, new meter profiles have been prepared and implemented for both meters installed in customers locations and meters installed in SSs. In the pilot area, the following devices are installed: municipal meters and sets of SSs (concentrator + meter for measuring the parameters)

37 The range of changes in parameters recorded by 1-phase municipal meters is presented in Table 5 TABLE 5: PARAMETRIZATION CHANGE FOR 1-PHASE CUSTOMER METER Before parametrization After parametrization Capture objects Description Acquired Acquisition period Acquired Acquisition period 1,0-0: ,2 load profile status X 60 min X 15 min 3,1-0: ,2 +A X 60 min X 15 min 3,1-0: ,2 -A X 60 min X 15 min 3,1-0: ,2 QI (+Ri) X 60 min X 15 min 3,1-0: ,2 QII (+Rc) - X 15 min 3,1-0: ,2 QIII (-Ri) - X 15 min 3,1-0: ,2 QIV (-Rc) X 60 min X 15 min 4,1-0: ,2 Pmax X 1 day X 15 min 3,1-0: ,2 U L1 - instantaneous - X 15 min 3,1-0: ,2 -A T1 - X 1 day 3,1-0: ,2 -A T2 - X 1 day The range of changes in parameters recorded by 3-phase municipal meters is presented in Table 6. TABLE 6: PARAMETRIZATION CHANGE FOR 3-PHASE CUSTOMER METER Capture objects Description Before parametrization Acquired Acquisition period After parametrization Acquired Acquisition period 1,0-0: ,2 load profile status X 60 min X 15 min 3,1-0: ,2 +A X 60 min X 15 min 3,1-0: ,2 -A X 60 min X 15 min 3,1-0: ,2 QI (+Ri) X 60 min X 15 min 3,1-0: ,2 QII (+Rc) - X 15 min

38 3,1-0: ,2 QIII (-Ri) - X 15 min 3,1-0: ,2 QIV (-Rc) X 60 min X 15 min 4,1-0: ,2 Pmax X 1 day X 15 min 3,1-0: ,2 U L1 - instantaneous - X 15 min 3,1-0: ,2 U L2 - instantaneous - X 15 min 3,1-0: ,2 U L3 - instantaneous - X 15 min 3,1-0: ,2 -A T1 - X 1 day 3,1-0: ,2 -A T2 - X 1 day The range of changes in parameters recorded by meters installed in SSs is presented in Table 7. TABLE 7: PARAMETRIZATION CHANGE FOR 3-PHASE CUSTOMER METER Capture objects Description Before parametrization Acquired Acquisition period Acquired After parametrization Acquisition period 3,1-0:32,7,124,255,2 3,1:0-52,7,124,255,2 3,1-0:72,7,124,255,2 Instantaneous TTHD of voltage L1 Instantaneous TTHD of voltage L2 Instantaneous TTHD of voltage L3 - X 10 min - X 10 min - X 10 min 3,1-0: ,2 P+ L1 - X 15 minutes 3,1-0: ,2 P+ L2 - X 15 minutes 3,1-0: ,2 P+ L3 - X 15 minutes 3,1-0: ,2 P- L1 - X 15 minutes 3,1-0: ,2 P- L2 - X 15 minutes 3,1-0: ,2 P- L3 - X 15 minutes 3,1-0: ,2 Q+ L1 - X 15 minutes

39 3,1-0: ,2 Q+ L2 - X 15 minutes 3,1-0: ,2 Q+ L3 - X 15 minutes 3,1-0: ,2 Q- L1 - X 15 minutes 3,1-0: ,2 Q- L2 - X 15 minutes 3,1-0: ,2 Q- L3 - X 15 minutes The changes were used and tested in tests of the deployed software. 2.2 THE INFORMATION SYSTEM A concept of the IT system implemented in the project was prepared during task T6.1 and is described in document D6.1 System Analysis. In the next step, in task T6.2 System Design, the technical design was prepared for the distinct functionalities. The newly designed and built IT system includes solutions supporting LV grid management. What is important in the implemented system is that it uses data from smart meters and new devices monitoring LV grid operation. A CIM was used to exchange information about the LV grid. The LV network model is compatible with the "CIM Model Repository for EOP" document. The basis for the CIM model is iec61970cim16v17_iec61968cim12v06_iec62325cim02v07. New IT solutions were built based on the existing systems: SCADA and AMI. The system architecture design is presented in Figure 8. The basic elements of the system are as follows: DMS LV which is essentially the AMI system extended with functions built as part of task 6.4, SCADA MV/LV, the SCADA system with additional data for the LV network. Based on the existing SCADA MV system, a LV grid layer was created, FCS application for mobile devices developed under the UPGRID project, UDP extension. The possibility was added for analyzing the effects of micro-generation installation

40 FIGURE 8: POLISH DEMO HIGH-LEVEL SYSTEM DESIGN

41 2.2.1 DISTRIBUTION MANAGEMENT SYSTEM FOR LV (DMS LV) DMS LV was built as an extension of the AMI system existing at ENERGA-OPERATOR. DSM LV uses the same data (selected from the demonstration area) as the AMI production system. To separate the studies of the developing of functionalities of the DMS system from the AMI production system, the architecture presented in Figure 9 was implemented. The architecture is designed to allow for tests and studies of the implemented system in the UPGRID project in ENERGA s IT environment. The solution made it possible to separate, as far as possible, the UPGRID system from the production environment of the AMI system. FIGURE 9: UPGRID SYSTEM ARCHITECTURE Based on the solutions designed in task T6.2 (as described in document D6.2, the chapter 10.2), new elements were added to the existing AMI application. The architecture of the new solution is presented in Figure 8. In this Figure, the following are marked with the indicated colours: Existing system elements not to be extended, Extended element or added new functionalities, New elements/functionalities. Specific logical modules of the system include sets of functionalities defined in document D6.2, the chapter 3. In Table 8, functionalities are listed for each module of the DMS system. The adopted logical division of the modules does not allow for their testing because of the fact that the developed functions are implemented in different modules (e.g. calculations are made in Network Analysis (NA), results displayed in Meter Data Management (MDM) and stored in Central Data Base (CDB)). Therefore, for the

42 purpose of this document, it has been assumed that the test results will be presented broken down into implemented functions rather than modules. TABLE 8: MODULES OF DMS Module name Scope New functionality implemented in demonstrator solution Meter Data Management (MDM) Meter Data Gateway (MDG) Network Control and Management (NCM) Management of meter data and events, web based graphical user interface. Acquisition of metering data and event data from the smart meters via Data Concentrator Unit. Functions for management of equipment and grid objects. SS view, showing SS parameters, monitored values, alarms and their thresholds in a table and on the map view of the LV grid, interface to SCADA MV/LV. List of SSs, details and statistic information, monitored values, alarms. Display SSs on map Management of power delivery points and measurements management, statistic and details information, Event acquisition and PRIME topology acquisition. DER connection and disconnection, automatic DER detection and fault isolation, interface to SCADA MV/LV. Meter data exchange between DMS and SCADA DER management Management of LV network topology (fault location and switching sequence, update LV grid topology) Transformer overload protection

43 Network Analysis (NA) Outage Management System (OMS) Functions Central Database (CDB) LV grid analytic functions Functions related to outage management Metering data, event data, LV grid model data, calculation output data and configuration data storage Power Flow calculations, transformer losses calculations, transformer optimization, interface to SCADA MV/LV. Power Flow calculations and result presentation in SCADA LV, Technical losses calculation and presentation for all SSs, Show grid state estimation results (historical data) Show generation and load forecast Display forecast power profile for the metering point Information about transformers (load, temperature) Transformer management, details information and optimisation Displaying network on a map. Interface to Outages and network operations ( Network Management System used in ENERGA (AiES), from Polish Awarie i Eksploatacja Sieci), System Average Interruption Duration Index (SAIDI) and System Average Interruption Frequency Index (SAIFI) calculations, interface to SCADA MV/LV. Calculation of indicators of energy supply quality, Fault detected by the DMS system and exchange information about failure between DMS and SCADA, display fault details and information on the map. New tables in Oracle database for LV grid model data and calculation output data. New PostgreSQL database for events and PRIME topology. In the DMS, the existing interface of the AMI production application is used. The system ensures security of use due to adopted at AMI rules of individual logging in by each user. The basic DMS LV interface is presented in Figure 10. New key functionalities of the DMS LV are available in the window Objects>Network. The Reports tab includes, among others, reports prepared within the DMS

44 FIGURE 10: DMS LV INTERFACE BASED ON SOLUTIONS FROM AMI

45 The system functionalities performed in the network window include: Window with a list of SSs and information of possible alerts, Parameters tab. In this window, detailed information about the SS is given and momentary data received from meters and calculations are provided. They are presented in Figure 11. FIGURE 11: PARAMETER VIEW (POL. PARAMETRY) Measurements tab. It includes charts of measurement data and presentation of calculation results. It provides the possibility of changing settings of alert levels. Real-time data are collected from meters installed in SSs or calculated by DMS LV. For each value, it is possible to set alert levels (upper and lower). If alert levels are exceeded, information about it is displayed next to the list of SSs. A sample view of the window is presented in Figure

46 FIGURE 12: MEASUREMENTS VIEW (POL. POMIARY) Topology tab. It includes a map of the network and visualization of measurement and calculation data. A real-time network topology is verified and updated in accordance with the operation arrangement in the SCADA LV system. The implemented filters make it possible to analyse possible excesses in this area. Geographical data of network elements are connected with their technical data. By indicating an object, it is possible to read them. Topology tab is shown on Figure

47 FIGURE 13: TOPOLOGY VIEW (POL. TOPOLOGIA Event log tab. Presentation of events concerning selected secondary substations. Topology tab is shown on Figure 14. FIGURE 14: EVENT LOG VIEW (POL. ZDARZENIA)

48 Window Transformer optimization possible. Presentation of possible transformer optimization results based on the criterion of reduction of technical losses (Figure 15). FIGURE 15: TRANSFORMER OPTIMIZATION RESULTS Analyses and reports are available in the Reports tab. Software tests were performed taking into account the functional scope presented in documents D6.2, the chapter 5. During the work on the construction and optimization of functionalities and the manner of operation, a user interface was prepared as presented above. The interface ensures access to new functionalities planned in the UPGRID project. In the interface, however, no division is maintained (e.g. handling in separate windows) for particular groups of functions: MDM, NCM, NA and OMS. In this manner, the interface adjusted to the needs of users ensures high functional advantages. Tests of the IT system described in chapter 4 are preceded by a table which matches the functionalities described in document D6.2, the chapter 5 to the arrangement of the interface in the final version of the IT system USER DATA PANEL (UDP) Within the UPGRID Polish Demo, the existing UDP was extended with additional features for energy generation simulation. UDP was developed by Atende Software an affiliated third party of ATENDE. Each customer living in the project area has the opportunity to calculate how much energy could be produced from a theoretical photovoltaic (PV) panel if it was installed at their premises (the user is

49 asked to define some panel characteristics such as efficiency, geographical orientation, etc.). All users have their own account with access to their data from smart meters Furthermore, the customer can compare his or her energy consumption with the simulated PV production. The monthly and daily view of simulation results are shown in Figure 16 and Figure 17. FIGURE 16: PV SIMULATION PANEL (MONTHLY SIMULATION) FIGURE 17: PV SIMULATION PANEL (DAILY SIMULATION)

50 2.2.3 FIELD CREW SUPPORT (FCS) The main window of the FCS application shows the map view of the network and offers an option for capturing and adding a picture of grid elements. Additionally, the application allows viewing the properties of the selected network element. Figure 18 shows the map view of the FCS. The objects that are visualized in the main map screen are SSs, grid nodes and line segments. The line segments marked in green are powered up whereas the line segments in yellow are not powered. The grid nodes having some normally open point have a yellow border. In case there is some active alarm on any object (e.g. SS), it is edged with red colour. The grid elements can be viewed in map view or in the table view (shown in Figure 19). For every object, one can access its properties (an example of properties screen is shown at Figure 20). The SS properties include transformer information as well as the latest readouts from the SS meter and the date of the last readout. FCS application also lists the metering points assigned to the grid node by simply clicking on it. This metering point view is shown in Figure 21. As already mentioned, another FCS functionality allows to take pictures that can be associated with grid objects and sent back to the SCADA system. FIGURE 18: FCS - MAP VIEW FIGURE 19: FCS - TABLE VIEW

51 FIGURE 20: FCS - SECONDARY SUBSTATION PROPERTIES FIGURE 21: FCS - NODES AND METERING POINTS SCADA MV/LV The SCADA LV system has been built based on the existing and operated SCADA MV system. SCADA LV uses the same data acquired from network monitoring (selected for the demonstration area) as the SCADA MV production system. To separate the tests of functionalities of the SCADA LV system from the SCADA MV production system, the architecture presented in Figure 22 was implemented. The architecture of the SCADA LV solution is based on the SCADA MV system operating in the Gdańsk Branch Office. The major functions of the SCADA MV solution included: 1. System operations the user may put graphic symbols on the substation and network diagrams associated with works performed on the objects. 2. Simulations the system makes it possible to perform a simulation of the operating state based on the level of a list of windows. 3. Retrospection checking the state of the object in the past, 4. Graphic interface of the operator with operating tools: event log,

52 maps and diagrams, lists, summaries, charts, reports. The structure of the SYNDIS MV system makes it possible in the process of data registration to manage the data statically and, above all, dynamically by: updating the composition of the state vector originating from telemechanics, executing control sequences, executing controls, statistics calculations. The architecture of the SCADA MV (Figure 22) system has been cloned to the SCADA LV system used in the UPGRID pilot project. Such a solution makes possible parallel read-outs from telemechanics drivers connected to the SCADA MV system and, at the same time, allows for sharing in a returnable way functionalities from the low voltage area in the SCADA LV system. The architecture of the pilot solution allows to verify data in terms of quality at the level of the SCADA MV system, providing a quality warranty for the data used in the functionalities of the SCADA LV system. Such a solution allows clearly for exchanging data and functions with the AMI/DMS system. FIGURE 22: SCADA LV SYSTEM ARCHITECTURE A network model from the GIS system has been implemented to the SCADA LV system. Based on this model, using the CIM standard, a diagram of the LV network has been generated automatically. A view from the main window of the system with the network visualization in a geographical area and with the diagram is presented in Figure 23 and Figure 24. In Figure 25, a view of the CIM structure is shown for a selected object in the network

53 FIGURE 23: SCADA- LV NETWORK ON THE MAP VIEW FIGURE 24: SCADA- LV NETWORK SCHEMA VIEW

54 FIGURE 25: SCADA- CIM MODEL VISUALISATION The basic assumption for the SCADA LV system was to use the existing SCADA MV interface. The system prepared in this way is a functional and effective tool for supporting the work of the traffic dispatcher. Similarly as in the case of SCADA MV, the following functions are provided in the SCADA LV solution: Possibility of network visualization and adjusting the view (scale, layers, change of view from map to scheme) for the needs of the dispatcher. An event log has been introduced (Figure 26). The event log automatically records information about events from the sensors installed in the network and provides the opportunity to enter data manually. In the event log, information coming from the DMS LV is recorded. Mapping operations have been introduced, involving the possibility of changing the position of connectors and adding extra information with graphic visualization. Analysis of network topology. Presentation of measurement data from sensors installed in the network. In Figure 27, a portion of the network is presented with a visualization of measurements in cable cabinets. The measurement is performed by the prototype devices described in chapter Visualizations of data about PV. Transmission of data to the DMS system. Receipt and visualization of data from the DMS system

55 FIGURE 26: SCADA LV WITH A VIEW OF THE EVENT LOG FIGURE 27: SCADA- LV CABLE CABINET WITH MONITORING

56 3 FUNCTIONAL TESTS OF THE NEWLY DEVELOPED FIELD DEVICES The tests covered the prototype devices described in section 2.1, developed and implemented under the UPGRID project: Prototype solutions for monitoring and supervising SSs integrated AMI/SG cabinets. Due to the application of these solutions, two types of solutions for SSSs have been developed. Prototype devices monitoring electrical parameters in LV cable cabinets. A prototype device allowing for steering and monitoring the operation of micro-generation. 3.1 FUNCTIONAL TESTS OF THE NEWLY DEVELOPED FIELD DEVICES SMART SECONDARY SUBSTATION DEVICES SPECIFICATION OF MEDIUM-VOLTAGE SECONDARY SUBSTATIONS AND SG DEVICES Table 9 presents a list of SSs where smart grid devices have been installed and indicates key functions performed by these devices. The functions have been tested in accordance with the testing procedures described in the chapter 2. Item TABLE 9: LIST OF MV SECONDARY SUBSTATIONS WITH SG DEVICES AND PERFORMED SG FUNCTIONS LV System MV functions functions SS no. SS name MV switchgear No. of MV fields 1 T-2089 Cmentarz RM6-IDI 3 2 T-2181 Szczecińska T-2183 Pomorska T-2188 Tatrzańska TPM- WLLL 4 No. of LV fields (1) 8 (2) 10 (6) 10 (3) 10 (4) Type Cabinet Controller General indications Remote control Current measurement (3) Voltage measurement on buses 2W Emiter Wago W 1W Lamel Lamel Mikronika Mikronika Fault passage detection (3) Current and voltage measurement Fuse link burn-out indication Comments 2W ZPUE IEnG (4)

57 System MV functions LV functions Item SS no. SS name MV switchgear No. of MV fields No. of LV fields (1) Type Cabinet Controller General indications Remote control Current measurement (3) Voltage measurement on buses Fault passage detection (3) Current and voltage measurement Fuse link burn-out indication Comments 5 T-2206 Wolności Szkoła (4) 1W Lamel Mikronika T-2208 Wolności DOMONT RM6 IDI 3 10 (4) 2W Emiter Wago T-2213 Tatrzańska Klasztor (9) 1W Lamel Mikronika T-2235 Wolności TPM WLLL 4 12 (5) 2W ZPUE IEnG T-2246 Nowogrodzka ABB CTC 3 12 (5) 2W (5) 10 T-2270 Stawna (4) 1W ZPUE IEnG T-2273 Jasna TPM WLLL 4 10 (9) 2W ZPUE IEnG T-2274 Witomino Radiostacja RM6- IDI 3 7 (7) 2W Emiter Wago T-2275 Rolnicza TPM WLLL 4 12 (5) 2W Lamel Mikronika T-2276 Narcyzowa (10) 1W Lamel Mikronika T-2313 Zjazdowa (6) 1W Lamel Mikronika T-2774 Narcyzowa I (10) 1W Lamel Mikronika T-2775 Narcyzowa II (2) 1W Lamel Mikronika T-2756 Wąska T-2757 Pasieczna T-2758 Mirtowa (3) 10 (3) 10 (4) 1W Emiter Wago W ZPUE IEnG W ZPUE IEnG

58 System MV functions LV functions Item SS no. SS name MV switchgear No. of MV fields No. of LV fields (1) Type Cabinet Controller General indications Remote control Current measurement (3) Voltage measurement on buses Fault passage detection (3) Current and voltage measurement Fuse link burn-out indication Comments 21 T-2759 Rozmarynowa (3) 1W ZPUE IEnG T-2760 Wielkokacka II RM6 IIDI 4 12 (6) 2W Lamel IEnG T-2761 Stawna I (8) 1W Emiter Wago TPM WLLL 4 10 (2) 2W Lamel 24 T-2762 Chwarznieńska Mikronika T-2763 Niska CA TPM WLL 3 10 (9) 2W Lamel Mikronika T-2764 Pionierów T-2765 Promienna (4) 8 (6) 1W ZPUE IEnG W Emiter Wago T-2766 Hodowlana I TPM WLLL 4 11 (7) 2W Emiter Wago T-2767 Profesorska (8) 1W Lamel Mikronika T-2768 Nauczycielska (9) 1W Lamel Mikronika T-2769 Sosnowa T-2770 Słoneczna T-2771 Konwaliowa I T-2772 Konwaliowa II T-2773 Małokacka T-2776 Cicha (4) 10 (7) 10 (6) 10 (8) 10 (8) 8 (4) 1W Emiter Wago W ZPUE IEnG W Emiter Wago W Emiter Wago W Emiter Wago W ZPUE IEnG

59 System MV functions LV functions Item SS no. SS name MV switchgear No. of MV fields No. of LV fields (1) Type Cabinet Controller General indications Remote control Current measurement (3) Voltage measurement on buses Fault passage detection (3) Current and voltage measurement Fuse link burn-out indication Comments 37 T-2777 Graniczna (9) 1W ZPUE IEnG T-2778 Witomino Hydrofornia TPM WLLL 4 8 (3) 2W Lamel IEnG T-2779 Zielna (2) 1W Emiter Wago T-2781 Łąkowa (3) 1W ZPUE IEnG T-2785 Tulipanowa (3) 1W ZPUE IEnG T-2787 Witawa RM6 DIDIDD 6 17 (17) 2W Emiter Wago T-2934 Chwarzno Przepomp. TPM WLLL 4 8 (8) 2W Lamel IEnG T-2938 Chwarzno Apisa (5) 1W Emiter Wago T-2940 Chwarzno Amona (6) 1W Lamel Mikronika T-2941 Chwarzno Marsa (4) 1W Lamel Mikronika T-2942 Chwarzno Zeusa RM6 IIDI 4 10 (5) 2W ZPUE IEnG T-2945 Chwarzno Okrężna (9) 1W Emiter Wago Comments: (1) In parentheses, the number of cable outflows is provided. (2) General indications: 230 VAC power failure, door opening, power failure in fields (3) 1W cabinets measurement and detection of faults in one outflow field, 2W cabinets measurement and detection of faults in two outflow fields

60 (4) The existing remote controlling system has been retained (modernization of the substation in 2015). (5) Absence of actuators and contacts in the equipment status indicators in the MV switchgear, modernization impossible OBJECT TESTS OF SMART GRID DEVICES SITE ACCEPTANCE TESTS For the devices listed in Table 9, Site Acceptance Tests (SATs) were performed with the following scope: 1. Test of general indications correct transmission of general object signaling: 230 VAC power failure, door opening, power failure in fields, remote control deactivation) to SCADA. 2. Test of data transmission from the MV switchgear and clearing of indications correct transmission of signals from the MV switchgear to SCADA, correct clearing of indications from the built-in protection in the circuit breaker field of the MV switchgear (opening the circuit breaker from the protection) with a command from SCADA. 3. Test of the indication of faults in MV line fields and clearing correct transmission of ground fault and short circuit signaling to SCADA, correct ground fault and short circuit indication clearing with a command from SCADA. 4. Test of MV switchgear fields control correct execution of control activities with connectors in MV switchgear from the SCADA system. 5. Test of LV fuse link burn-out indication correct transmission of a signal on fuse link damage (burn-out) in the low voltage switchgear to the SCADA system. 6. MV current and voltage measurements correct transmission of current and voltage measurements on the MV side by measuring components of the fault indication system to the SCADA system. 7. LV current, voltage and capacity measurements correct transmission of measurements (currents, voltages, capacity) recorded by grid parameter measuring instruments installed in the LV switchgear to the SCADA system. A detailed specification of Site Acceptance Tests performed in each SS is presented in Table 10. The tests were carried out in accordance with the procedure described below REQUIRED EQUIPMENT AND INSTRUMENTATION Universal measuring instrument: enabling measurement of AC voltage of 230 V, enabling measurement of DC voltage of 24 V,

61 containing an acoustic/optical circuit continuity indicator; Current transformer for measuring phase current of the FPI; Single-phase current inductor enabling the induction of alternating current of tens of amperes with the possibility of measuring this current with an accuracy of 1 A. Wire sections PREPARATION FOR THE TESTS Preparatory work for the tests included: Turn on the 230 VAC power supply to the SG cabinet, Turn on the battery power supply, Turn on the power supply of the MV switchgear (protection in the control cabinet), Activate remote control of the MV switchgear with a switch in the remote control cabinet, Turn on the protection of the Sulfur hexafluoride 6 (SF6) pressure control circuits (1FS1, applicable to TPM switchgear), Turn on the protections of actuators in the line fields (2F1, 3F1,..., applicable to MV switchgear type TPM), Activate remote control with switches in the line fields (Remote control item, applicable to TPM switchgear), Confirm in the Regional Capacity Dispatch that communication exists between the controller and SCADA TESTING PROCEDURE The detailed procedures for the performance of the tests specified in Table 10 are described in sections The following rules were observed for the performance of the tests. The + signs and the letters a, b,... in Table 10: Specifications of Site Acceptance Tests performed in each MV substation have the following meanings: The + sign means that all tests must be performed in compliance with the procedure, The letters a, b,... mean that only those tests that are marked with the specific letters must be performed as part of the detailed procedures. After the completion of each test, the system was restored to its previous condition

62 Item SS no. SS name Table 10: Specifications of Site Acceptance Tests performed in each MV substation General indications Indications from MV switchgear and clearing of indications from MV protection MV switchgear fields control Tests Fault indication and clearing Fuse link burnout indication MV current and voltage measurement LV current, voltage and capacity measurements Sections T-2089 Cmentarz + c, e, h + + a 2 T-2181 Szczecińska a, b + a 3 T-2183 Pomorska a, b + a 4 T-2188 Tatrzańska Not applicable (substation modernized in 2015) 5 T-2206 Wolności Szkoła 6 T-2208 Wolności DOMONT 7 T-2213 Tatrzańska Klasztor a, b + a + c, e, h + + a a, b + a 8 T-2235 Wolności a 9 T-2246 Nowogrodzka Not applicable (substation not modernized) 10 T-2270 Stawna a, b + a 11 T-2273 Jasna a + 12 T-2274 Witomino Radiost. + c, e, h + + a 13 T-2275 Rolnicza T-2276 Narcyzowa a, b + a 15 T-2313 Zjazdowa a, b + a 16 T-2774 Narcyzowa I a, b + a 17 T-2775 Narcyzowa II a, b + a 18 T-2756 Wąska a, b + a 19 T-2757 Pasieczna a, b + a 20 T-2758 Mirtowa a, b + a

63 Item SS no. SS name General indications Indications from MV switchgear and clearing of indications from MV protection MV switchgear fields control Tests Fault indication and clearing Fuse link burnout indication MV current and voltage measurement LV current, voltage and capacity measurements Sections T-2759 Rozmarynowa a, b + a 22 T-2760 Wielkokacka II + c, e, h + + a 23 T-2761 Stawna I a, b + a 24 T-2762 Chwarznieńska a 25 T-2763 Niska CA T-2764 Pionierów a, b + a 27 T-2765 Promienna a, b + a 28 T-2766 Hodowlana I a 29 T-2767 Profesorska a, b + a 30 T-2768 Nauczycielska a, b + + a + 31 T-2769 Sosnowa a, b + a 32 T-2770 Słoneczna a, b + a 33 T-2771 Konwaliowa I a, b + a 34 T-2772 Konwaliowa II a, b + a 35 T-2773 Małokacka a, b + a 36 T-2776 Cicha a, b + a 37 T-2777 Graniczna a, b + a 38 T-2778 Witomino Hydrof a 39 T-2779 Zielna a, b + a 40 T-2781 Łąkowa a, b + a 41 T-2785 Tulipanowa a, b + a 42 T-2787 Witawa + c, e, h + + a

64 Item SS no. SS name General indications Indications from MV switchgear and clearing of indications from MV protection MV switchgear fields control Tests Fault indication and clearing Fuse link burnout indication MV current and voltage measurement LV current, voltage and capacity measurements Sections T-2934 Chwarzno Przepomp a 44 T-2938 Chwarzno Apisa a, b + a 45 T-2940 Chwarzno Amona 46 T-2941 Chwarzno Marsa 47 T-2942 Chwarzno Zeusa 48 T-2945 Chwarzno Okrężna a, b + + a + a, b + a + c, e, h + + a a, b + a TEST OF GENERAL INDICATIONS Preparatory and completion activities are described in the introduction to this section. Perform the tests described below one by one. For 1W cabinets, only tests described in items a) and b) are performed. a) Door opening: Close all doors indications in SCADA are cleared, Opening any door will activate the indication, Perform the check for all doors of the facility. b) 230 VAC power failure: Indications in SCADA are cleared, Open the 230 VAC power supply of the cabinet the indication is activated, Turn on the 230 VAC power supply of the cabinet the indication is cleared, c) Field (actuator) power failure: Indications in SCADA are cleared, Open the 24 VDC field power supply protection the indication is activated, Turn on the 24 VDC field power supply protection the indication is cleared. d) Remote control deactivation:

65 Indications in SCADA show that remote control is activated for the whole MV switchgear, Set the remote control switch to Deactivated (off) SCADA indicators show deactivation of remote control of the MV switchgear, Set the remote control switch to Activated (on) SCADA indicators show activation of remote control of the switchgear TEST OF INDICATIONS FROM THE MV SWITCHGEAR AND CLEARING OF INDICATIONS FROM THE MV PROTECTION Preparatory and completion activities are described in the introduction to this section. All checks must be performed in compliance with the documentation (diagrams) of secondary circuits of the MV switchgear. The indications associated with SF6 tested in items a) and b) are applicable to the TPM switchgear only and are shared by the whole switchgear. In accordance with the documentation of the object instrumentation, differences must be taken into account in the equipment of disconnector and circuit-breaker fields of the RM6 and TPM switchgear Arrange the possibility of changing the positions of connectors with the traffic controller. The remaining indications listed in the procedure must be executed separately for each field a) Voltage drop in SF6 control circuits and failure in line fields: Indications in SCADA are cleared Open the 1FS1 protection in the TPM switchgear in SCADA the Voltage drop in SF6 control circuits indication is activated (general indications) and the Failure indication is activated (all disconnector fields). Turn on the 1FS1 protection all activated indications are cleared. b) Sulphur hexafluoride (SF6) pressure drop: Indications in SCADA are cleared, Short the indication circuit terminals in the TPM switchgear when joined together, the SCADA indications are activated. c) Status of the remotely controlled (two-bit) disconnector / circuit breaker: Indications in SCADA show a status consistent with the actual position of the disconnector switch. Change the status of the disconnector: If the traffic controller permits switching exercise local control (using control buttons or lever), If there is no permission for the switching perform a status change simulation through the corresponding connection and disconnection of indication circuits in accordance with the documentation a status change of the connector in SCADA occurs. Restore the connector or connections in the indication circuits to the status existing prior to the test d) Disconnector status in the circuit breaker field (applicable to TPM):

66 Perform the activities provided for in item c) for the disconnector. e) Earthing switch status: Perform the activities provided for in item c) for the earthing switch. f) Remote control deactivation in the field: Indications in SCADA show that remote control in the field has been activated. Turn the remote control switch in the field to Local or Deactivated indications in SCADA show that remote control in the field has been deactivated. Turn the remote control switch in the field to Remote indications in SCADA show that remote control in the field has been activated. g) Power failure of 24 VDC actuators: Indications in SCADA are cleared. Turn off the 2F1, 3F1,... protections in the fields of the TPM switchgear the SCADA indication of a 24 VDC power failure is activated. Turn on the 2F1, 3F1,... protections in the fields of the TPM switchgear the indication of the absence of a 24 VDC power supply is cleared. h) Actuation of the protection in the circuit breaker cubicle (cell) (opening of the circuit breaker from the protection). RM6 switchgear Indications in SCADA are cleared Short the contacts of the indication of actuated protection in the circuit breaker field when the circuit is closed, the indication becomes activated TPM switchgear Indications in SCADA are cleared activate the indication maintenance relay of actuated protection in the circuit breaker field the indications become activated in SCADA and locally Go to item i) i) Clearing of the indication of actuated protection in the TPM switchgear (activation in accordance with item h) ): Indications in SCADA and locally are activated. Send a command from SCADA to clear the indication on the object. Indications in SCADA and locally are cleared. Note: the clearing command is collective for the whole substation and clears also fault indications TEST OF THE INDICATION OF FAULTS IN MV LINE FIELDS AND CLEARING OF FAULT INDICATIONS Preparatory and completion activities are described in the introduction to this section. The indications listed in the procedure must be executed separately for each field:

67 Indications in SCADA are cleared. If a remote test function is available in SCADA, send a command to test the indications. If the remote test function is unavailable, activate the indicator using the local test button. SCADA and local indications become activated (in the fault indication module). Send a command from SCADA to clear the indication on the object. Indications in SCADA and locally are cleared TEST OF MV SWITCHGEAR FIELDS CONTROL Preparatory and completion activities are described in the introduction to this section In accordance with the documentation, for each field in the MV switchgear check the control method of the field: If the control involves exposing voltage from the control cabinet to control coils, a voltmeter with a 24 VDC range should be used for the test If the control involves closing the control circuit with a potential-free contact in the cabinet (control voltage exposed from the switchgear), a circuit continuity indicator should be used for the test The indications listed in the procedure must be executed separately for each field The disconnector fields are controlled for the on and off positions, the transformer circuit breakers are controlled only for the off position Arrange the possibility of performing control commands on the object: Send a command from SCADA to control the field. If the traffic controller has permitted connector control operations, the connector position is changed, This fact is reflected in SCADA. If there is no permission to control the connector, disconnect the control circuit wires on the terminal bar in the MV switchgear, connect a meter (voltmeter or continuity meter) to the circuit and check if the control circuit has been activated (through the appearance of a 24 VDC control voltage or circuit continuity indication). For the disconnector, perform the activity in both directions (for close and open ). After opening, the circuit breaker needs to be closed using the local control lever. After the completion of the tests, reconnect the previously disconnected wires TEST OF LV FUSE LINK BURN-OUT INDICATION Preparatory and completion activities are described in the introduction to this section. The test is performed only in SSs equipped with the functionality of fuse link burn-out indication. The fuse link burn-out signal is collective for the whole LV switchgear, yet the test must be performed for each switchgear field separately: Prior to the test, the SCADA indications are cleared. Press the Test button on the switch fuse in the LV switchgear. The SCADA and local (if a local indicator exists) indications become activated

68 Press the Test button again on the disconnector. The indications are cleared. The test must be repeated for all fields of the LV switchgear from which LV outflows have been routed MV CURRENT AND VOLTAGE MEASUREMENTS Preparatory and completion activities are described in the introduction to this section. The test is performed for each measured field and each phase separately. Perform the test of a correct voltage measurement on MV buses (b) only in SSs equipped with this kind of measurement. During the tests, take into consideration the fact that the measurements presented in SCADA are updated at specific intervals (every several dozen seconds), as set in the SCADA communication hub. a) MV current measurement: Disconnect the current transformer from the terminal bar in the SG cabinet (for working currents in the primary winding, the transformers are resistant to work with an open secondary winding) In the place of the disconnected current transformer, connect a test transformer to the SG cabinet through the measuring window of which the current wire of an AC inductor is routed Set the setpoint on the inductor. Perform the following two tests: for a current of approx. 10 A for a current near the maximum value that may be generated by the inductor Compare the value of the induced current with the value shown in SCADA. The difference between the indications should not be greater than 1 A. Disconnect the test transformer and connect the current measurement transformer installed in the switchgear (disconnected prior to the test). Repeat the activity in all measured fields and in all phases. b) Voltage measurement on MV buses: Depending on the configuration of the measurement transformer connections, measure the phase-to-phase or phase voltages on the secondary side of the voltage measurement circuit (on the terminals in the SG cabinet). Calculate the voltage on the primary side according to the transformer value provided in the object documentation. The phase-to-phase voltage should be approx. 15 kv and the phase voltage should be approx. 8.6 kv. Compare the values of the measured voltages (calculated for the primary side) with the values presented in SCADA. The difference between the indications should not be greater than 0.1 kv. Repeat the activity in all measured fields and in all phases

69 LV CURRENT, VOLTAGE AND POWER MEASUREMENTS Preparatory and completion activities are described in the introduction to this section: Compare the values of voltages, currents and capacities measured by the local indicators installed in the LV switchgear fields with the values shown in SCADA. The difference between the voltage indications should not be greater than 5 V. For the currents and capacities, the difficulty in making such comparisons results from the following: significant variability of offtake volumes averaging period for the measurements shown on the displays of the local meters long data update duration in SCADA The comparison of measurements must be repeated for all fields of the LV switchgear from which LV outflows have been routed TEST RESULTS 1. The test of general indications, the test of fault indication and clearing and the test of MV current and voltage were performed in all SSs to the extent consistent with the installed devices. Test result: positive 2. The test of indications from the MV switchgear and clearing of indications from the MV protection and the test of MV switchgear fields control were performed in 14 MV SSs. Test result: positive. 3. The tests of LV current, voltage and capacity measurements were performed in two SSs. Test result: positive. The test results are presented in Table 11. TABLE 11: RESULTS OF SITE ACCEPTANCE TESTS PERFORMED IN EACH SECONDARY SUBSTATIONS Item SS no. SS name General indications Indications from MV switchgear and clearing of indications from MV protection MV switchgear fields control Tests Fault indication and clearing Fuse link burn-out indication MV current and voltage measurement LV current, voltage and capacity measurements Rozdział T-2089 Cmentarz a 2 T-2181 Szczecińska a, b + a 3 T-2183 Pomorska a, b + a 4 T-2188 Tatrzańska Not applicable (substation modernized in 2015) 5 T-2206 Wolności Szkoła a, b + a

70 Item SS no. SS name General indications Indications from MV switchgear and clearing of indications from MV protection MV switchgear fields control Tests Fault indication and clearing Fuse link burn-out indication MV current and voltage measurement LV current, voltage and capacity measurements Rozdział T T-2213 Wolności DOMONT Tatrzańska Klasztor + c, e, h + + a a, b + a 8 T-2235 Wolności a 9 T-2246 Nowogrodzka Not applicable (substation not modernized) 10 T-2270 Stawna a, b + a 11 T-2273 Jasna a + 12 T-2274 Witomino Radiost. + c, e, h + + a 13 T-2275 Rolnicza T-2276 Narcyzowa a, b + a 15 T-2313 Zjazdowa a, b + a 16 T-2774 Narcyzowa I a, b + a 17 T-2775 Narcyzowa II a, b + a 18 T-2756 Wąska a, b + a 19 T-2757 Pasieczna a, b + a 20 T-2758 Mirtowa a, b + a 21 T-2759 Rozmarynowa a, b + a 22 T-2760 Wielkokacka II + c, e, h + + a 23 T-2761 Stawna I a, b + a 24 T-2762 Chwarznieńska a 25 T-2763 Niska CA T-2764 Pionierów a, b + a 27 T-2765 Promienna a, b + a

71 Item SS no. SS name General indications Indications from MV switchgear and clearing of indications from MV protection MV switchgear fields control Tests Fault indication and clearing Fuse link burn-out indication MV current and voltage measurement LV current, voltage and capacity measurements Rozdział T-2766 Hodowlana I a 29 T-2767 Profesorska a, b + a 30 T-2768 Nauczycielska a, b + + a + 31 T-2769 Sosnowa a, b + a 32 T-2770 Słoneczna a, b + a 33 T-2771 Konwaliowa I a, b + a 34 T-2772 Konwaliowa II a, b + a 35 T-2773 Małokacka a, b + a 36 T-2776 Cicha a, b + a 37 T-2777 Graniczna a, b + a 38 T-2778 Witomino Hydrof a 39 T-2779 Zielna a, b + a 40 T-2781 Łąkowa a, b + a 41 T-2785 Tulipanowa a, b + a 42 T-2787 Witawa + c, e, h + + a 43 T T T T T-2942 Chwarzno Przepomp. Chwarzno Apisa Chwarzno Amona Chwarzno Marsa Chwarzno Zeusa a a, b + a a, b + + a + a, b + a + c, e, h + + a

72 Item SS no. SS name General indications Indications from MV switchgear and clearing of indications from MV protection MV switchgear fields control Tests Fault indication and clearing Fuse link burn-out indication MV current and voltage measurement LV current, voltage and capacity measurements Rozdział T-2945 Chwarzno Okrężna a, b + a EVALUATION OF TEST RESULTS The purchased and installed prototype solutions for the monitoring and control of SSs were implemented in the pilot area. Before the commencement of the tests, the stabilization process was executed. During the stabilization, in some devices the controller software was modified. The solutions of one of the suppliers in the 2W option required reconstruction of the cabinet and adjustment to the existing LV switchgear. Because 2W solutions offer the functionality of remote switching of MV switchgear units, they required particular care in the implementation and use in the actual network. By using AMI/SG cabinet solutions, practical verification was performed of the possibility of applying monitoring and control functions in the existing SSs. For this purpose, 1W solutions were used. Thanks to these solutions and the extension of the AMI system, it became possible to monitor the operation of MV and LV networks. It was confirmed the readiness of solution providers on the Polish market to quickly adjust their offerings to the needs of ENERGA-OPERATOR SA. During the start-up and testing, the prototype 1W and 2W AMI/SG cabinets required changes in both the software and the cabinet connection system. The fixes were successfully implemented by the providers of the pertinent solutions. The start-up and testing process demonstrated the need to clarify the technical specifications prepared for the 1W and 2W solutions. In 2W solutions, a significant challenge was the absence of a standard for the signals monitoring and controlling the MV switchgear. The providers of MV switchgear have their own solutions in this area. As a consequence, this required changes in the AMI/SG cabinet connection systems and customization of controller software. The experience gained in the UPGRID project has already been taken advantage of by ENERGA- OPERATOR SA. Based on the prepared technical specifications and the experience gained during the installation of prototype AMI/SG cabinets in the UPGRID demonstration area, new monitoring and control standards in SSs are being introduced in The new solutions, referred to as SSS, have been implemented in all SSs

73 3.2 LV NETWORK MONITORING DEVICES LOW VOLTAGE SUBSTATIONS EQUIPPED WITH FAULT CURRENT DETECTION DEVICES Table 12 contains a list of low voltage cable cabinets in which fault current detection devices have been installed. TABLE 12: LIST OF LOW VOLTAGE CABLE CABINETS WITH FAULT CURRENT DETECTION DEVICES DETAILED INFORMATION ABOUT THE SCOPE OF MONITORING IN INDIVIDUAL MEASUREMENT CABINETS No. Name of cable cabinet Number of cable cabinet SS Numbers of feeders Number of faults detectors 1 Malinka Z-4C/SKLEP/406 T Widna 3 kl.viii Z-3A/1021 T Widna 3 kl.ii Z-3B/1021 T Pogodna 2 kl.i Z-2A/402 T Widna 7A kl.i Z-7A/1021 T Widna 5 kl.i Z-5A/1021 T Pogodna 4 kl.iv Z-9D/1021 T Nauczycielska 8B Z-8/406 T Nauczycielska 16B Z-16/406 T OBJECT TESTS OF SMART GRID DEVICES SITE ACCEPTANCE TESTS For the devices listed in Table 9, Site Acceptance Tests (SATs) were performed the scope of which included: 1. Test of general indications, correct transmission of general object signals: 230 VAC power failure, door opening, battery discharge) to SCADA. 2. Test of fault indication and clearing: correct transmission of fault occurrence signals to SCADA, correct ground fault and short circuit indication clearing with a command from SCADA. 3. LV current, voltage and capacity measurements, correct transmission of current and voltage measurements in LV output fields measured in the fault signaling system to SCADA REQUIRED EQUIPMENT AND INSTRUMENTATION Measuring instrument enabling measurement of AC voltage of 230 V, Clamp meter enabling measurement of alternating current of up to 200 A, Wire sections

74 3.2.4 PREPARATION FOR THE TESTS Preparatory work for the tests included: Turn on the 230 VAC power supply to the LDLV cabinet, Turn on the battery power supply, Confirm in the Regional Capacity Dispatch that communication exists between the controller in the LDLV cabinet and SCADA TESTING PROCEDURE The tests were performed in accordance with the detailed procedures described in sections After the completion of each test, the system was restored to its previous condition TEST OF GENERAL INDICATIONS Preparatory and completion activities are described in the introduction to this section Perform the tests described below one by one: a) Door opening: Close all doors indications in SCADA are cleared Opening any door will activate the indication Perform the check for all doors of the facility b) 230 VAC power failure: Indications in SCADA are cleared Open the 230 VAC power supply of the cabinet the indication is activated Turn on the 230 VAC power supply of the cabinet the indication is cleared c) Battery discharge Indications in SCADA are cleared The shorting of the BAT LOW terminals in the power supply will activate the indications TEST OF THE INDICATION OF FAULTS IN LV LINE FIELDS AND CLEARING OF FAULT INDICATIONS Preparatory and completion activities are described in the introduction to this section. The indications listed in the procedure must be executed separately for each field: Indications in SCADA are cleared. Press the TEST button in the indicator module in the controller SCADA and local indications become activated (an LED in the indication module)

75 Send a command from SCADA to clear the indication on the object. Indications in SCADA and locally are cleared. The indications may also be cleared locally by re-pressing the TEST button LV CURRENT AND VOLTAGE MEASUREMENTS Preparatory and completion activities are described in the introduction to this section. The test is performed for each measured field and each phase separately During the tests, take into consideration the fact that the measurements presented in SCADA are updated at specific intervals (every several dozen seconds), as set in the SCADA communication hub. a) MV current measurement: Put on a clamp meter on the live wire of the low voltage cable and watch the current value on the instrument Compare the current value read on the measuring instrument with the values shown in SCADA. The difference between the current indications should not be greater than 2 A. The difficulty in making such comparisons results from the following: - significant variability of offtake volumes - averaging period for the measurements shown on the displays of the local meters - long data update duration in SCADA Repeat the activity in all measured fields and in all phases. b) Voltage measurement on MV buses. Connect a voltmeter to the connection terminals of the voltage measurement circuit in the LDLV cabinet and watch the readings of the instrument. Phase voltage is measured. Compare the voltage value read on the measuring instrument with the values shown in SCADA. The difference between the voltage indications should not be greater than 5 V. Repeat the activity in all measured fields and in all phases TEST RESULTS The object checks performed on 17 and 21 February 2017 covered all the installed devices. It was found that the devices operate properly and that the transmission of signals, controls and measurements between the object controller and SCADA is correct: Door opening indication correct, Power failure indication correct, Battery discharge indication correct Activation of the fault indicator, local and remote indications correct, Clearing of an activated fault indicator correct, Measurement of currents and voltages, transmission to SCADA and visualization in SCADA correct

76 3.2.7 EVALUATION OF TEST RESULTS The functions of the applied prototype solutions for LV cable network monitoring are fulfilled completely. Measurement information is visualized in the SCADA LV system. UPS use in cable cabinets enables the transmission of information on fault currents. This information may help find the locations of failures in the LV network and thus reduce the duration of interruptions in the supply of electricity. In combination with the LV switchgear installed in SSs on each circuit, this changes the process of data collection on LV network failures. The previous system, based predominantly on customer notifications of power failures, is being replaced with a new system. In the new solution, the DSO receives information about failure from the implemented monitoring devices. This enables the DSO to take much faster action to restore the supply of electricity. The taking of such action does not require notification of the power failure by the customers, because information about the failure is obtained from the sensors installed in the LV network. This solution may be used in areas where a high quality of power supply is required. In the future, these kinds of solutions may also be used to monitor the network with DER accumulation. The development of electro-mobility supported by the Polish government may also generate the need for the monitoring of electrical parameters within the LV network. 3.3 DER MONITORING AND CONTROL (LVMC) DEVICES The description of the tested device is presented in the Section The purpose of the functional tests described in this section was to verify the correct implementation of the DER LVMC devices functions defined in the project. 7 test cases were prepared and executed. The test cases were as follows: 1. Read the current date and time from the LVMC device. 2. Read the A- register from the inverter. 3. Read the contactor status from the inverter. 4. Control the inverter contactor disconnect the contactor. 5. Control the inverter contactor connect the contactor. 6. Read a profile from the LVMC device. 7. Read the instantaneous power P DESCRIPTION OF TEST PROCEDURES The test procedures described in the following section require the execution of the following related preliminary activities via the web interface of the data concentrator:

77 Connect and log on to the data hub, as shown in Figure 28. FIGURE 28 DATA CONCENTRATOR LOGIN SCREEN Find and mark device IEN on the TOPOLOGY list, as shown in Figure 29. FIGURE 29: DATA CONCENTRATOR TOPOLOGY DEVICE SELECTION PROCEDURE FOR TEST PT1: READ THE CURRENT DATE AND TIME FROM THE DEVICE 1. On the right-hand side of the hub s web interface, go to the DETAILS tab. 2. In the CLOCK section, select the Download command, as shown in Figure In the Time field, the date and time read from the device will appear. FIGURE 30: DATA CONCENTRATOR CLOCK COMMANDS 4. Compare the read date and time values with the value displayed by the computer. The data hub retrieves time from NTP servers and then periodically synchronizes it on all PLC devices (nodes) that have been registered on the data hub. Assuming that the PC also retrieves time from NTP servers, the time obtained from the LVMC device and the PC should be the same READING THE A- REGISTER FROM THE INVERTER 1. On the right-hand side of the hub s web interface, go to the DETAILS tab. 2. In the MANUAL READING (DLMS) section in the box Query select a query DLMS on the value of the register follows A:

78 c ff and then select the Done button, as shown in Figure 31. FIGURE 31: DATA CONCENTRATOR QUERY FOR A- REGISTER 3. If you are prompted to provide an access token, enter the appropriate value and select the Continue button, as shown in Figure 32. FIGURE 32: DATA CONCENTRATOR SECURITY TOKEN INPUT 4. The registry read will appear in the Answer box, as shown in Figure 33. FIGURE 33: DATA CONCENTRATOR RESPONSE TO QUERY FOR A- REGISTER 5. The last 8 bytes (16 characters) are the HEX value of the read A- register. 6. After changing the HEX value to a DEC value, the resulting quantity in watt-hours [Wh] corresponds to the amount of electricity generated in the PV installation. 7. Compare the read A- register value with the value displayed by the inverter. If the readings are the same, this means that the value of the A- register has been correctly retrieved by the LVMC device

79 READING THE CONTACTOR STATUS FROM THE INVERTER 1. On the right-hand side of the hub s web interface, go to the DETAILS tab. 2. In the CONTACTOR section, select the Retrieve command. 3. In the Status box, the read value will be displayed ( OK indicates that the contactor is on and Off indicates that the contactor is disconnected), as shown in Figure 34. FIGURE 34: DATA CONCENTRATOR DISCONNECTOR STATUS 4. Compare the status that has been read with information on the inverter display ( Power > 0 indicates that the contactor is on, Standby indicates that the contactor is disconnected CONTROL THE INVERTER CONTACTOR DISCONNECT THE CONTACTOR 1. On the right-hand side of the hub s web interface, go to the DETAILS tab. 2. In the CONTACTOR section, select the Turn Off command, as shown in Figure If you are prompted to provide an access token, enter the appropriate value and select the Continue button, as shown in Figure In the Status box, information will appear that the contactor has been disconnected ( Off indicates that the contactor is disconnected). FIGURE 35: DATA CONCENTRATOR DISCONNECTOR CONTROL 5. Compare the status that has been read with information on the inverter ( Standby indicates that the contactor is disconnected). If the disconnector statuses are the same, this means that the LVMC device has properly transmitted the command to disconnect the contactor

80 CONTROLLING THE INVERTER CONTACTOR CONNECTING THE CONTACTOR 1. On the right-hand side of the hub s web interface, go to the DETAILS tab. 2. In the CONTACTOR section, select the Turn On command. 3. If you are prompted to provide an access token, enter the appropriate value and select the Continue button, as shown in Figure In the Status box, information will appear that the contactor has been connected ( OK indicates that the contactor is connected), as shown in Figure 36. FIGURE 36: DATA CONCENTRATOR DISCONNECTOR CONTROL 5. Compare the status that has been read with information on the inverter ( Power > 0 indicates that the contactor is on). If the disconnector status is the same, this means that the LVMC device has properly transmitted the command to disconnect the contactor READING A PROFILE FROM THE LVMC DEVICE 1. On the right-hand side of the hub s web interface, go to the PROFILES tab. 2. For OBIS code , retrieve a.csv file. FIGURE 37: DATA CONCENTRATOR AVAILABLE DEVICE PROFILES 3. Check if the retrieved CSV file contains 15-minute profiles presenting the generated electricity READING THE INSTANTANEOUS POWER P - 1. On the right-hand side of the hub s web interface, go to the DETAILS tab. 2. In the MANUAL READING (DLMS) section, in the Query box, enter the following DLMS query for the value of the instantaneous power P-: c ff 02 00, and then select the Execute button, as shown in Figure

81 FIGURE 38: DATA CONCENTRATOR QUERY FOR INSTANTANEOUS P- REGISTER 3. If you are prompted to provide an access token, enter the appropriate chain of characters and select the Continue button, as shown in Figure The registry read will appear in the Answer box, as shown in Figure 39Figure 50. FIGURE 39: DATA CONCENTRATOR RESPONSE TO QUERY FOR INSTANTANEOUS P- REGISTER 5. The last 4 bytes (8 characters) are the HEX value of the read instantaneous power. 6. After changing the HEX value to a DEC value, the resulting number reflects the instantaneous active power released to the network, expressed in watts [W]. Compare the read instantaneous power value with the value displayed by the inverter. If the readings are the same, this means that the value of the instantaneous power has been correctly read by the LVMC device TEST RESULTS Table 13 shows the results of LVMC test. Test code PT1 PT2 Test type Read the current date and time from the LVMC device. Read the A- register from the inverter. TABLE 13: RESULTS OF LVMC TEST Test results Value read from the device: :58 Value read on the computer: :58 HEX value read: cd3c After the conversion to DEC: 2,346,300 Wh = 2,346 kwh Value read from the inverter display: 2,346 kwh

82 PT3 Read the contactor status from the inverter. PT4 Disconnect the contactor on the inverter. PT5 Control the inverter contactor The contactor was connected. connect the contactor. PT6 Read a profile from the LVMC device. PT7 Read the instantaneous power P. HEX value read: DC After the conversion to DEC: 732 W Value read from the inverter display: 732 W The value read from the inverter is the same as the information shown on the inverter display. The contactor was disconnected. The profile was read correctly from the LVMC device. The profile contained correct data EVALUATION OF TEST RESULTS Laboratory tests of the DER inspection device enabled the verification of the correct implementation of the PV inverter monitoring and control functions through the LVMC device. During the tests of the devices and implementation works, they were verified and adjusted to EOP standards. As a result, the prototype devices fulfill the functionality planned in the UPGRID project. Due to difficulties in obtaining permission to install the DER devices, only one such device was installed in the field. During the field tests, a significant obstacle was unstable PLC communication. The place of installation of the LVMC device does not guarantee uninterrupted communication. Despite the use of repeaters, stable communication was not achieved. At the current stage of the work, sufficient communication quality is not ensured to support DER operation switchings. For field testing of the device, additional work is required, for instance the installation of PLC PRIME repeaters with an amplified signal strength. Laboratory tests of the device and the functionality of the IT systems have confirmed the ability to control PV installations. For this purpose, however, it is necessary to make sure that the device is connected to the IT system

83 4 FUNCTIONAL TESTS OF THE SOFTWARE FUNCTIONALITIES The following table maps use cases defined in D6.2, the chapter 5 to the components/modules of the system and to the test cases that were performed during task 6.5. Some of the use-cases were not implemented. The reason for that is stated in the Remarks column. For some use cases a test case was not performed this concerns the use cases for which the old AMI mechanisms were used. Function Use Case D6.2 Module Test case Remarks Users sign in DMS-001 MDM NO used old AMI mechanism User sign out DMS-002 MDM NO used old AMI mechanism Reporting SAIDI and SAIFI OMS-100 MDM DMS024 Reporting mechanisms MDM-080; MDM-081; MDM-082; MDM-083; MDM-084; MDM-085; MDM-086; MDM-087; MDM-088; MDM-089 MDM NO used old AMI mechanism Threshold configuration DMS-010 MDM DMS Enter a weather forecast DMS-011 MDM Not implemented implemented as an interface to weather forecast of openweathermap.org Display a list of SS MDM-068 MDM DMS1 Initially AMI view was supposed to be used, but at the end an entire new view was developed Display balancing statistics MDM-073 MDM DMS009 Display SSs on map MDM-071 MDM DMS2 Display SS details MDM-074 MDM DMS1 Initially AMI view was supposed to be used, but at the end an entire new view was developed Initially AMI view was supposed to be used, but at the end an entire new view was developed

84 Function Use Case D6.2 Module Test case Remarks Show system log for SSs MDM-065 MDM DMS022 Display statistics for selected SSs MDM-072 MDM DMS Show histogram for selected SSs MDM-090 MDM Not implemented Display Power Delivery Point (PPE) list MDM-054 MDM NO used old AMI mechanism Display PPE details MDM-055 MDM NO used old AMI mechanism Display the list of Metering Point (PP) MDM-042 MDM NO used old AMI mechanism Display PP details MDM-044 MDM NO used old AMI mechanism Show measurement sheet MDM-029 MDM NO used old AMI mechanism Perform network state estimation NA-014 NA DMS017 Instead power flow implemented and giving exactly same results Send alarm to the SCADA system NA-017 NA DMS009-DMS015 Show technical losses for selected SS NA-016 NA DMS012 Display technical losses profile for grid element NA-020 NA DMS023 Show grid state estimation results NA-019 NA DMS017 Show detailed state estimation results for grid element NA-021 NA Not implemented Show generation and load forecast NA-022 NA Not implemented It was decided not to make Graphical User Interface (GUI) interface since this step does not bring added business value Estimation is calculated but not shown

85 Function Use Case D6.2 Module Test case Remarks Display forecast power profile for the Metering Point NA-023 NA Not implemented Display information about transformer load NA-018 NA DMS011 Adjust transformer temperature NA-024 NA Not implemented Show/hide map layer NA-030 NA DMS2, DMS025 Select the range of displayed values NA-031 NA DMS2, DMS025 Change time or time interval for presented values NA-032 NA DMS009-DMS015 Display a list of transformers NA-005 NA DMS027 Display transformer details NA-006 NA DMS1, DMS027 Estimation is calculated but not shown Use case excluded, instead calculations are automatic and based on the weather data acquired from openweathermap.org Select the optimal transformer model for the substation NA-002 NA Generate transformer optimization report NA-011 NA DMS4, DMS020, DMS 021 DMS4, DMS020, DMS 021 Display transformers for substation NA-007 NA DMS1 Display a list of transformer models NA-004 NA DMS027 Display transformer technical data sheet NA-003 NA DMS

86 Function Use Case D6.2 Module Test case Remarks Delete transformer model NA-008 NA DMS027 Add transformer model NA-009 NA DMS027 Edit transformer technical data sheet NA-010 NA DMS027 Send voltage measurements to the SCADA system NCM-020 NCM DMS017 Display a list of DER sources NCM-007 NCM DMS3 Add DER NCM-001 NCM NO DER is a PP used old AMI mechanism Delete DER NCM-004 NCM NO DER is a PP used old AMI mechanism Display DER details NCM-008 NCM NO DER is a PP used old AMI mechanism Display DER for PPE NCM-009 NCM NO DER is a PP used old AMI mechanism Show PP for DER NCM-005 NCM Not implemented Further analysis shown that DER should be interpreted as PP Edit DER NCM-002 NCM NO DER is a PP used old AMI mechanism Display history of DER control NCM-006 NCM NO DER is a PP used old AMI mechanism Update LV grid topology NCM-013 NCM DMS019 Determine fault location and switching sequence NCM-014 NCM DMS018 Detect overloaded transformers NCM-016 NCM DMS011 Find new grid configuration to alleviate transformer NCM-017 NCM Test case moved to the algorithms Instead network optimisation was implemented described in

87 Function Use Case D6.2 Module Test case Remarks overload chapter algorithms section Calculate SAIDI and SAIFI OMS-001 OMS DMS005; DMS006 Submit information on potential failure to SCADA OMS-002 OMS DMS008 Verify Failure OMS-003 OMS DMS008 Display fault details OMS-006 OMS DMS005 Display faults on map OMS-007 OMS Not implemented Log in to the application FCS-001 FCS NO Log out of the application FCS-002 FCS NO Take a picture of the network element FCS-008 FCS FCS007 Display network elements on a map FCS-009 FCS FCS001 Information about probable fault is sent to SCADA Display element properties FCS-010 FCS FCS003; FCS004; FCS005; FCS006 Search for an object - FCS FCS002 Select a meter UDP-001 UDP NO Show meter details UDP-002 UDP NO Display information about power quality UDP-003 UDP Not implemented Excluded from the project Change time period for data presentation UDP-004 UDP UDP001 Simulate renewable energy source UDP-005 UDP UDP

88 Function Use Case D6.2 Module Test case Remarks Change simulation parameters UDP-006 UDP UDP001 Display list of Metering Points UDP-007 UDP NO used old AMI mechanism Search for Metering Points UDP-008 UDP NO used old AMI mechanism Manage the display of power quality information UDP-009 UDP Not implemented Excluded from the project Power flow calculations - NA DMS017 DER management SCADA-001, SCADA- 002, SCADA-003, SCADA-009 SCADA LV SCADA1 LV network topology management SCADA-010, SCADA- 011, SCADA-014, SCADA LV SCADA2 Fault detection, isolation and restoration system (FDIR) for LV network SCADA-004, SCADA- 005, SCADA-006, SCADA-007, SCADA- 008, SCADA-012, SCADA LV SCADA3 Transformers management SCADA-013 SCADA LV SCADA4 4.1 DMS LV TESTS In the DMS area, a number of tests were prepared and performed. New functionalities designed and implemented in the demonstration area were tested. These functionalities are described in section The set of tables presented below describes the purpose and scope of the tests and the results of selected tests

89 4.1.1 DMS1 - SECONDARY SUBSTATION MONITORING - DISPLAY OF MEASURED VALUES Description: The purpose of the test is to verify whether the measurement values displayed by DMS are consistent with the values recorded by the balancing meter. Initial conditions: Operating DMS with active data acquisition from the balancing meter. Active user account in DMS. Steps: 1. Log in to DMS 2. From the system menu, select Network 3. Select a SSs with current measurements 4. Read the measurement values displayed in the PARAMETERS tab for: a. Instantaneous current b. Instantaneous voltage c. Instantaneous power d. Total Harmonic Distortion of the voltage waveform (THDU) 5. Compare the read values with the values available in the Measurements tab of the measurement point for the balancing meter 6. Compare the read values with the current readings of the balancing meter available online from the hub (perform the reading by downloading 10-minute and 15- minute profiles of the balancing meter) Expected results: 1. The values read in the Parameters tab are the same as the values available in the Measurements tab of the measurement point for the balancing meter 2. The values read online from the hub are consistent with the values read in the Parameters tab Results: The result of the performed test is positive. For selected SSs, the values of the following parameters were compared: instantaneous current, instantaneous voltage, instantaneous power and THDU. The verification was performed by comparing, for selected times, the data displayed in the Parameters window and in the meter database

90 4.1.2 DMS2 - SECONDARY SUBSTATION MONITORING - VIEW ON THE MAP Description: The purpose of the test is to verify the correct display of the network topology on the map. Initial conditions: Operating DMS and SCADA. Active user accounts in DMS and SCADA. Steps: 1. Select a substation 2. Open the TOPOLOGY tab 3. Compare the topology of the selected SS on the background map in DMS with the topology in SCADA a. Perform the comparison for each SS in the Witomino area Expected results: 1. The DMS and SCADA systems contain the same data on the location of the SSs, nodes, line sections and Measurement Points. Results: The maps displayed in the SCADA LV and DMS LV systems were compared the result was positive. In Figure 40 sample network segments displayed in DMS LV is shown. FIGURE 40: VIEW MAPS IN DMS LV

91 4.1.3 DMS3 - DISPLAY THE LIST OF DER Description: The purpose of the test is to verify the possibility to display a DER list in the system. Initial conditions: Active user account in DMS. Steps: 1. Select the Measurement Points view 2. Select a grouping containing the rule: TAG CONTAINS { DER } Expected results: 1. The system displays a list of measurement points for which electricity increases were recorded in the release direction during the last month Results: The result of the performed test is positive. A list of meters was obtained in which electricity generation was recorded (electricity transfer to the network). The results were verified for 2 meters (observable increases in A-). Figure 41 below shows a DMS LV system window with selected customers equipped with a DER. FIGURE 41: DMS LV LIST OF CUSTOMERS WITH A DER

92 4.1.4 DMS4 - CALCULATION OF TRANSFORMER LOSSES IN THE OPTIMIZATION MODULE Description: The purpose of the test is to verify whether the transformer optimization module correctly calculates losses based on data obtained from the substation s balancing meter. Initial conditions: Operating DMS with active data acquisition from the balancing meter. Active user account in DMS. Steps: 1. Log in to DMS 2. From the system menu, select Network 3. Select a substation for which the transformer optimization is possible 4. In the Parameters tab, click on the link reading transformer optimization possible 5. Read the current losses in the table (together with the period for which they were calculated) 6. Return to the Parameters tab and click the link to the balancing meter 7. On the meter sheet, click the Measurements tab. 8. Define the same measurement range as that for the transformer optimization window 9. Estimate the average annual losses based on transformer catalog data, the differences in annual electricity increments and the average voltages measured by the balancing meter (the calculation formula is provided in a separate spreadsheet: DMS004.xlsx) Expected results: 1. The ratio of the values in the optimization window to the estimated results should be within the range of 90%-110% Results: The test was performed on the selected SS: Chwarznieńska 2762 Transformer losses in the optimization window: kwh Loss calculation period: from June 2016 to June

93 Values read in the balancing meter s window: 1 June June 2016 A+ [kwh] Ri- [kvarh] Rc+ [kvarh] Annual electricity increments: A+ [kwh] R+ [kvarh] Input data: Multiplicand 200 P [kw] Q [kvar] S [kva] Average voltage [V] 227 Transformer rated power [kva] 250 Transformer Cu losses [kw] Transformer Fe losses [kw] Loss calculation results: Load losses [kwh] No load losses [kwh] Losses [kwh] Ratio of estimated losses to losses calculated in DMS: 92.56%. Test result: positive

94 4.1.5 DMS5 - CALCULATIONS OF SAIDI AND SAIFI Description: The purpose of the test is to verify whether the SAIDI and SAIFI values are calculated properly. Initial conditions: Operating DMS with active data acquisition from the balancing meter. Active user account in DMS. Steps: 1. Log in to DMS 2. From the system menu, select Network 3. Select a substation 4. Read the SAIDI and SAIFI values from the PARAMETERS tab (the former value is calculated based on data from AIES and the latter value is calculated based on power failure events) 5. Read the reconnections that were taken into account for the SAIDI and SAIFI calculations (clicking the SAIDI or SAIFI value will present a table with reconnections obtained from AIES) 6. Compare the data on the reconnections on a given substation with data in the AIES system. 7. Verify consistency of the SAIDI and SAIFI calculations with the following formulas: Expected results: 1. DMS and AIES have the same outage data (after step 6). 2. SAIDI and SAIFI are correctly calculated, i.e. consistent with the applicable formulas (after step 7) 3. The results of the SAIDI and SAIFI calculations based on outages from AIES and based on actual events are inconsistent. After ranking the results according to step 9, explain the reasons for the discrepancies for the two substations with the greatest discrepancies for each type of ranking. t i - power supply interruption duration, n i - number of customers deprived of power supply, N - number of all customers, i - number of interruptions (scheduled / unscheduled outage) 8. For each substation in the project area, compare the SAIDI and SAFI calculations based on data obtained from AIES and based on actual events. 9. Rank the substations considered in item 8 in the following order: a. SAIDI calculations: from the largest to the

95 smallest difference in SAIDI values between the calculations based on AIES and actual events b. SAIDI calculations: from the largest to the smallest difference in SAIDI values between the calculations based on actual events and AIES c. SAIFI calculations: from the largest to the smallest difference in SAIFI values between the calculations based on AIES and actual events d. SAIFI calculations: from the largest to the smallest difference in SAIFI values between the calculations based on actual events and AIES Results: The following substations were selected: Hodowlana I 2766, Pomorska 2183, Cicha Data for the Pomorska 2183 substation according to AIES: SAIDI 30m SAIFI 1.6 Data for the Pomorska 2183 substation according to the PLC analysis: SAIDI 55m SAIFI 0.2 Conclusions: The value of SAIDI according to AIES is smaller than that according to the PLC analysis. The reason for this difference is that in the PLC analysis more data are collected than are available in AIES. Probably, the differences in data were caused by problems in communication via the power network between the meters and the hub, which in certain cases causes incorrect failure predictions. In turn, the value of SAIFI is smaller than that obtained in the PLC analysis. For the Pomorska substation, three outages had occurred since the beginning of the year, two of which happened on the same date at a short interval. During the PLC analysis, probably the interval between the outages was too short and two actual outages were detected as one longer-lasting outage. This resulted in a smaller SAIFI value. Data for the Hodowlana I 2766 substation according to AIES: SAIDI 28m SAIFI 0.2 Data for the Hodowlana I 2766 substation according to the PLC analysis: SAIDI 1h 1m SAIFI

96 Conclusions: In this case, the values of both SAIDI and SAIFI are higher according to the PLC-based failure analysis. As in the previous case, the algorithm is flawed by the problem of inaccurate detection of failures due to the communication problem between the meters and the hub. Data for the Cicha 2776 substation according to AIES: SAIDI 1h 38m SAIFI 0.6 Data for the Cicha 2776 substation according to the PLC analysis: SAIDI 1h 27m SAIFI 1.0 Conclusions: The values of SAIDI and SAIFI are similar for both methods. According to the PLC analysis, SAIDI is slightly higher, which may have been caused by an incorrect treatment of one actual outage as several distinct outages, for instance in situations where the meters maintained communication with the hub for a short moment and AIES failed to record this fact DMS6 - CALCULATIONS OF SAIDI AND SAIFI CUT-OFF TEST Description: The purpose of the test is to verify the system response to a cut-off of a group of customers on the network. Initial conditions: Operating DMS with active data acquisition from the balancing meter. Active user account in DMS. Ability to cut off the supply of power to customers. Steps: 1. Select a SS with which there are no communication problems, i.e. data from the meters are collected at least every 2 hours Expected results: 1. An increase in the SAIDI and SAIFI values confirms the number of customers who have been cut off 2. Cut off the supply of power to the customers on the selected SS for more than 3 minutes 3. Check the results of the SAIDI and SAIFI calculations 4. Repeat this verification of the results of the SAIDI and SAIFI calculations each day

97 Results: Selected SS: Zielna The planned cut-off lasted from 00:47:00 to 02:01:00 for 58 meters. In the AMI system, this cut-off was recorded together with one additional outage from 01:30:00 to 01:58:00. The reason for it was the appearance of redundant data about outages in the file transmitted from AIES. The additional outage has the same number of cut-off customers and the same order number. These were the only outages recorded in this SS since the beginning of the year. The number of all customers necessary to calculate the indices is determined based on data obtained from SCADA. According to these data, during the cut-off, 56 Measurement Points were powered by the Zielna 2779 SS. Due to the discrepancy in the number of customers, the values of the indices differ by an error of approx. 3.45%. Leaving the data errors aside, the SAIDI and SAIFI calculation algorithms work properly. For the two outages, which lasted for a total of 102 minutes for 58 recipients, the algorithm correctly calculated the indices relative to the number of all customers connected to the substation during the outages (according to data obtained from SCADA). Since the beginning of the year, the number of power outages per each one of the 56 recipients of this SS was approx. 2.1 times for a total duration of 1h 46m DMS7 - FAILURE DETECTION BASED ON PLC Description: The purpose of the test is to verify whether DMS will detect a failure based on the parameter s threshold value, where the reference values will be data recorded by the balancing meter. Initial conditions: Operating DMS with active data acquisition. Active user account in DMS. Steps: 1. Define the customers subject to the cut-off. 2. Cut off the defined group of customers for at least one hour. 3. Read the threshold value for fault detection (METER_FAILURE_THRESHOLD, VAR table) 4. Wait for an hour after resuming the power supply 5. From the upgrid_meter_failure_log table select those meters whose probability_value field is greater than the value retrieved in step 3 and the entry was made after the cut-off date Expected results: 1. The unique list of meters is the same as the list of customers subject to the cut-off, as defined in item 1. Results: The list of meters is the same as the defined list of customers the result is positive

98 4.1.8 DMS8 - FAILURE DETECTION BASED ON PLC TRANSMISSION OF INFORMATION TO SCADA Description: The purpose of the test is to verify whether the results of the operation of the failure detection algorithm are transmitted from DMS to SCADA. Initial conditions: Operating DMS with active data acquisition. Active user account in DMS. Operating SCADA with an active communication with DMS. Steps: 1. Define the customers subject to the cut-off. 2. Cut off the defined group of customers for at least one hour. Expected results: 1. After a maximum of 3 hours after the resumption of power supply to the customers, DMS will transmit to SCADA a list of customers potentially affected by the failure. Results: Within 3 hours, DMS transmitted a list of customers affected by the failure the result is positive. The communication interface does not provide for the possibility of calling off a failure. A failure call-off initiated by DMS LV should be added. Figure 42 presents a SCADA window view with the visualization of a failure area (based on data obtained from DMS LV) FIGURE 42: VIEW OF RECEIVED FAILURE MESSAGES IN SCADA

99 4.1.9 DMS9 DMS15 MONITORING OF SECONDARY SUBSTATIONS ALARMS The tests included verification of the correct displaying of alarms transmitted from DMS LV to SCADA LV regarding: Transformer voltages on the LV side, Transformer loads, Currents on the LV side, Total Harmonic Distortion (THD), Losses in the transformer and line sections. Description: The purpose of the test is to verify the correct operation of the SS alarm mechanism. Initial conditions: Operating DMS with active data acquisition from the balancing meter. Active user account in DMS. Steps: 1. Select a SS 2. Open the MEASUREMENTS tab Expected results: 1. The system should detect a balancing alarm on the SS and the results should be visible in DMS and SCADA Results: 3. Select the appropriate graph 4. Set the alarm threshold values so that the currently measured values are outside the threshold range 5. Monitor the alarms on the SS in DMS and SCADA Test results: positive. Alarms appearing in DMS LV are transmitted to SCADA LV. Figure 43 presents a sample view of alarms and visualizations in the SCADA LV diagram. Figure 44 presents a view of the measurement tab in DMS LV with a sample graph and a set alarm level

100 FIGURE 43: SCADA-LV, DISPLAY OF ALARMS FIGURE 44: DMS LV, MEASUREMENTS TAB

101 DMS16 FLOW CALCULATIONS TRANSMISSION OF INFORMATION TO SCADA Description: The purpose of the test is to verify whether the results of the flow calculations, i.e. voltages, currents, capacities and losses are transmitted from DMS to SCADA. Initial conditions: Operating DMS with active data acquisition. Active user account in DMS. Active user account in SCADA. Unobstructed communication between the systems. Steps: 1. Select a network segment containing nodes with electricity recipients assigned to them 2. Check that flow calculations have been performed for this network segment Expected results: 1. SCADA acquired the measurement values for the nodes from DMS 3. Verification of the retrieved measurement values from DMS in SCADA Results: Measurement data were sent from DMS to SCADA the result was positive. Verification of communication with SCADA on 6 September 2017, for P-4/435 a measurement of 300V was sent manually, the result appeared in SCADA (positive). The results are presented in Figure 45. FIGURE 45: SCADA- PRESENTATION OF MEASUREMENT DATA

102 Figure 46 presents the results calculated automatically by DMS LV. FIGURE 46: SCADA- PRESENTATION OF MEASUREMENT DATA IN NODES DMS18 ISOLATION OF NETWORK ELEMENTS IN THE EVENT OF A FAILURE Description: The purpose of the test is to verify whether DMS isolates indicated network elements in a manner enabling an increase in the number of recipients covered by electricity supplies. Initial conditions: Active communication between SCADA and DMS Steps: 1. SCADA sends an FDIR sequence preparation request (GetSwitchingPlans) 2. DMS confirms receipt of the request message (GetSwitchingPlansResponse) 3. DMS prepares switching sequences. 4. DMS sends the prepared switching sequences to SCADA (CreatedSwitchingPlans) Expected results: 1. SCADA contains information about connectors the status of which needs to be changed in order to isolate a network element. 2. The number of customers is increased after the change in the connector statuses 5. SCADA sends a message receipt confirmation to DMS (CreatedSwitchingPlansResponse)

103 Results: The test result was negative. The assumptions for the graphs of connections between network elements have been insufficient. The problem of representing dependencies is a complex problem and requires further investigation. After the tests have been completed, the data model will be changed so that the connection information includes the detected problems DMS19 RECEIVING OBJECT STATUSES FROM SCADA Description: The purpose of the test is to verify whether DMS receives information about the object statuses transmitted from SCADA. Initial conditions: Operating DMS and SCADA. Active user account in DMS. Active user account in SCADA. Steps: 1. Change the status of an object in SCADA (e.g. fuse status, measurement) 2. When an object status change event occurs, a message is sent (ChangedMeasurements) 3. The message is received by DMS 4. DMS sends a receipt confirmation message (ChangedMeasurementsResponse) Expected results: 1. The object status changed in DMS 2. SCADA received confirmation that the message had been sent Results: Objects in DMS were changed the result was positive DMS20 SELECTION OF THE OPTIMAL TRANSFORMER Description: The purpose of the test is for DMS to select the optimal transformer. Initial conditions: Operating DMS with an algorithm calculating losses on the transformer. Active user account in DMS

104 Steps: 1. Select a SS marked with an icon indicating a possible optimization of the transformer. 2. In the SS details, go to the Parameters tab and click the link to the window presenting proposed transformer models. 3. Enter the unit price of energy and the cost of replacement of each transformer. Expected results: 1. The system presents proposed transformer models the use of which will generate lower losses. 2. After introducing the unit price of electricity and the replacement cost for each transformer, the system presents the period of return of the investment in the replacement of each transformer. Results: For selected SSs with an alarm indicating a transformer optimization possibility, the period of return of the cost of replacement of the transformer was reviewed vis-à-vis loss reduction costs. In the demonstration area, a significant part of the transformers operates below the maximum capacity, which offers ample room for changes and a decrease in losses. Tests of the final effect of loss reductions in the transformers will be conducted at a later stage in the project DMS21 GENERATION OF A REPORT ON THE POSSIBILITY OF TRANSFORMER OPTIMIZATION IN THE SECONDARY SUBSTATION Description: The purpose of the test is for DMS to select the optimal transformer. Initial conditions: Operating DMS with an algorithm calculating losses on the transformer. Active user account in DMS. Steps: 1. Select a SS marked with an icon indicating a possible optimization of the transformer. 2. In the SS details, go to the Parameters tab and click the link to the window presenting proposed transformer models. 3. Enter the unit price of energy and the cost of replacement of each transformer. 4. Right-click below the table with the proposed transformers and click the command Download a report. Expected results: 1. The system launches the report download. 2. The report contains the same data on the proposed transformers as those that were presented in the system. Results: SS: Chwarzno Przepompownia 2934 result: positive. A report was generated in DMS, containing the same data on the proposed transformers result: positive

105 DMS22 PRESENTATION OF THE LOG OF EVENTS FOR A SECONDARY SUBSTATION Description: The purpose of the test is to present a log of events for the selected power SS. Initial conditions: Active user account in DMS. Steps: 1. Select the Log tab. 2. Using the filtering tool, select Source = Substation. 3. Using the filtering tool, enter the number of the searched SS as the value of the Object field. Expected results: 1. The system presents events associated with the indicated SS. Results: Test result: positive. In the Events tab, all event logs are recorded for each SS DMS23 MONITORING OF SECONDARY SUBSTATIONS LOSSES ON LINE SECTIONS Description: The purpose of the test is to verify the correct operation of the line loss alarm mechanism for the SS. Initial conditions: Operating DMS with active data acquisition from the balancing meter. Active user account in DMS. Steps: 1. Select a SS 2. Open the MEASUREMENTS tab 3. Select the graph Losses on line segments 4. Set the alarm threshold values (max) so that the currently measured values are above the threshold value 5. Monitor the alarms on the SS in DMS and SCADA Expected results: 1. The system should detect a loss alarm on the SS and the results should be visible in DMS and SCADA

106 Results: In the Measurements tab, the results of the calculation of losses in line sections are available. A sample of loss visualization is shown in Figure 47. FIGURE 47: DMS LV CHART OF LOSSES IN LINE SEGMENTS DMS24 SAIDI AND SAIFI REPORT GENERATION Description: The purpose of the test is to verify the correct operation of the SAIDI and SAIFI report generation mechanism. Initial conditions: Active user account in DMS. Steps: 1. From the system menu, select SAIDI/SAIFI. 2. In the New tab, enter the report parameters and click the Generate button. 3. Go to the Reports tab and wait for the system to generate a report with the name entered in the previous step. 4. Click the XLS icon. Expected results: 1. Saving the SAIDI and SAIFI report on the user s hard drive. 2. The report should include the name of the SS and the calculated SAIDI and SAIFI

107 Results: A report was generated in DMS, containing a list of the SSs in the project area and the calculated SAIDI and SAIFI result: positive DMS25 PRESENTATION OF BACKGROUND MAPS Description: The purpose of the test is to verify the correct display of the selected layers on the map. Initial conditions: Operating DMS and SCADA. Active user accounts in DMS and SCADA. Steps: 1. Select a SS 2. Open the TOPOLOGY tab 3. Expand the menu on the right-hand side. 4. Select the layers to be displayed. Expected results: 1. The system displays a map screen with the background selected by the user. Results: As part of the test, functions executed in the Topology tab were verified. The map lets the user change the scale, display selected layers and filter the obtained results. For the selected objects, technical data are displayed. Test result: positive DMS26 PRESENTATION OF SELECTED ENGINEERING CALCULATIONS Description: The purpose of the test is to verify the correct display of the selected engineering calculations on the map. Initial conditions: Operating DMS and SCADA. Active user accounts in DMS and SCADA. Steps: 1. Select a SS 2. Open the TOPOLOGY tab 3. Expand the menu on the right-hand side. 4. From the Filtering area, select the calculations to be displayed. Expected results: 1. The system displays a map screen presenting the SSs consistent with to the selected filter

108 Results: The correct display of selected calculation and alarm results was verified. Test result: positive. Figure 48 presents a sample map view showing SSs with an exceeded THDU level marked in red. FIGURE 48: MAP VIEW ALARMS WITH EXCEEDED THDUS DISPLAYED DMS27 PRESENTATION OF THE LIST OF TRANSFORMERS Description: The purpose of the test is to verify the correct display of the list of transformers. Initial conditions: Operating DMS. Active user accounts in DMS. Steps: 1. Select Settings -> Device types -> Transformers 2. Click the selected transformer 3. Select Settings -> Device types -> Transformers -> Cogwheel icon -> Add 4. Specify the transformer parameters in the New transformer window and confirm 5. Click the new transformer in the list Expected results: 1. The system displays the list of transformers. 2. The system displays the details of the selected transformer

109 Results: 6. Change the transformer parameters and save the changes 7. Remove the transformer DMS LV correctly displays the list of transformers. Figure 49 presents a sample list with displayed details for the selected transformer. The functionality of editing, adding and deleting transformers was tested. Test result: positive. FIGURE 49: DMS LV LIST OF TRANSFORMERS DMS LV - EVALUATION OF TEST RESULTS DMS LV is equipped with functionalities which enable the use of smart meter data to support network management. It uses data available in real time and executes analyses based on data collected over selected periods. After the tests have been performed, it should be verified if the developed software fulfils the project requirements, i.e. if it enhances the monitoring and control of the low-voltage network. The effectiveness of these functionalities will be analysed over the subsequent months of the project. The algorithms for section isolation and network optimization require further testing in order to eliminate errors and then develop recommendations for the implementation of the developed solutions to the remaining areas of the network. Promising is the algorithm for the detection of potential failures based on communication with PLC. As of today, it has been confirmed (by way of controlled outages) that the algorithm correctly identifies failures. Full tests should cover actual failures, with particular emphasis on verification whether or not

110 the implementation of the algorithm resulted in an earlier reaction to failures. The applied algorithm may be used to: indicate potential failures in the LV network (information obtained from PLC communication analysis before receiving reports of power failure from customers), in the event of power outage reports from customers, use the functionality to determine the range of failure (the area affected by the failure). Such information should enable a quicker location of the failure. In both cases, this functionality will permit the shortening of interruptions in the supply of electricity. The newly developed MV/LV SS monitoring solutions, i.e. the ability to define alarm thresholds on the DMS side, integration of DMS and SCADA using CIM, transmission of measurement information (from the meter to the SS) and alarm information, should be recommended for implementation throughout the operator s network. The implementation of the monitoring solution deployed in the UPGRID project will enable the provision of measurement data and information on alarm in the LV network to the personnel of the power dispatch centre without incurring any expenditure on the installation of additional equipment in the SS. EOP has approx. 15,000 SSs where this newly developed solution may be implemented immediately. Functionalities associated with reducing technical losses included the following two areas: optimizations of LV network operation and changes in the network connection structure to achieve a reduction in losses on LV line sections, analysis of losses in MV/LV transformers and selection of optimal transformer power levels aimed at minimizing losses. This functionality enables an economic analysis of such activities. Taking into account the cost of electricity and the transformer replacement costs, the period is indicated during which such an action will bring a positive economic effect. The specific nature of the demonstration area indicates that there are considerably greater opportunities for reducing the loss level by replacing the transformers (currently, the transformers operate at a very low load level) rather than by optimizing the network division points. A very significant element supporting LV network management is the newly launched interface between DMS LV and SCADA LV. This interface enables the dispatcher to use DMS LV information and manage traffic through the SCADA interface. In this manner, efficient use of data by the traffic dispatch centre is ensured. 4.2 UDP1 - SIMULATION OF PV GENERATION Tests were carried out for the correct calculation and display of forecasted values of electricity generation. Description: The purpose of the test is to verify whether or not the UDP application properly simulates PV generation

111 Initial conditions: Account on the website Electricity Offtake Point in the UPGRID project area. Steps: 1. The user selects an Electricity Offtake Point in the Witomino area. The user selects the SIMULATION tab. 2. Change the time range of the presented calculation results. Expected results: 1. The simulation results are consistent with the results of the computational model: 2. Correctly displayed results after a change in the time range. Results: Test 1: positive result. The results obtained in the Simulation tab are consistent with the calculations available in the model. The results are presented in Figure 50. FIGURE 50: UDP VIEW OF SIMULATED ELECTRICITY GENERATION ON AN ANNUAL BASIS Test 2: positive result. The results obtained after changing the time range are presented in Figure

112 FIGURE 51: UDP VIEW OF SIMULATED ELECTRICITY GENERATION AFTER CHANGING THE TIME RANGE UDP - EVALUATION OF TEST RESULTS The role of UDP is to provide practical information to customers. Each customer in the demonstration area was provided with a simple possibility of simulating PV installation effects taking into consideration the following factors: Sunlight intensity and weather conditions in the area of residence, Possible PV capacity for installation by the customer. Customers obtain a result that takes into account their electricity consumption needs. This solution fits into the striving for increased customer participation and provides them with reliable knowledge. This solution will be recommended for implementation to all electricity consumers using UDP. 4.3 FIELD CREW SUPPORT (FCS) TESTS Tests were performed to verify the correct operation of the implemented functionality of the mobile FCS application

113 4.3.1 FCS1 - MAP VIEW Description: The purpose of the test is to verify whether or not the FCS application properly displays the map. Initial conditions: Mobile device with Internet access and Access Point Name (APN) enabling access to the FCS server in EOP. Under the default settings, the map presents the area within a 500 meter radius from the user s estimated position the position is determined based on Global Positioning System (GPS) geolocation. If GPS is unavailable, the position is determined on the basis of the Access Point ( AP) to the Internet using the logical address. Access to the Internet is necessary to use the application (but it can work without GPS access). Steps: 1. The user starts the application 2. The user logs in to the application Expected results: 1. The system displays the main screen the map screen 2. The system displays LV network objects in the user s vicinity 3. The user may zoom in the map up to a radius of 10 meters and zoom it out up to a radius of 2 kilometres. Results: FIGURE 52: FCS - MAP VIEW Objects are displayed on the map in accordance with the application design Error! No se encuentra el origen de la referencia.. Visualization of the network is enabled on the background maps. Test result: positive

114 4.3.2 FCS2 - FINDING OBJECTS Description: The purpose of the test is to verify whether or not the FCS application properly finds objects. Initial conditions: Mobile device with Internet access and APN enabling access to the FCS server in EOP. Steps: 1. The user is logged in to the application 2. The user goes to the map 3. The user presses the List button 4. A window is displayed with a list of objects and a find box 5. The system displays a list of objects that match the search criteria 6. The user clicks the arrow next to the selected object 7. Comparison of object parameters in DMS Expected results: 1. The system displays a screen with object-related information 2. The object parameters are consistent with the parameters available in DMS Results: FIGURE 53: FCS - LIST VIEW FCS displays a list of objects located near the place selected on the map Figure 53 lists of objects provides access to detailed information about each object. Test result: positive

115 4.3.3 FCS3 FCS 6 - DISPLAYING OBJECT PARAMETERS The scope of the test included displaying key data about the objects: Cable cabinets, Transformer SSs, Measurement points, Line sections. Description: The purpose of the test is to verify whether or not the FCS application properly displays the object parameters. Initial conditions: Mobile device with Internet access and APN enabling access to the FCS server in EOP. Steps: 1. The user is on the map screen 2. The user clicks on the SS icon 3. Comparison of object parameters in DMS Expected results: 1. The system displays a screen with SS-related information 2. The object parameters are consistent with the parameters available in DMS Results: The application provides access to detailed data about objects: SSs, cable cabinets, measurement points, line sections. Test result: positive. A sample application window with information about SSs is presented in Figure 54. FIGURE 54: FCS - SS DETAILS

116 4.3.4 FCS7 TRANSMISSIONS OF PHOTOGRAPHS TO SCADA LV Description: The purpose of the test is to verify whether or not the FCS application properly displays the object parameters. Initial conditions: Mobile device with Internet access and APN enabling access to the FCS server in EOP. Steps: 1. The user clicks on the selected object 1. The system displays a screen with objectrelated information 2. The system displays a window with object-related information 3. The user clicks the Photo button 4. The application switches to camera mode 5. The user takes a photograph 6. User clicks the save button (check mark) 7. The system displays a send the photo screen 8. The user selects the Comment box 9. The user enters a comment 10. The user clicks the Send button 11. The system displays a message Do you want to send the photo with the added comment? 12. The system sends the photograph and the comment to DMS 13. DMS sends the photo to SCADA 14. Verification of the availability of the photograph and comment in SCADA Expected results: 1. The photograph and comment are SCADA Results: The system enables the taking of photographs. The photograph is forwarded to SCADA and located on the mapped according to its geographic coordinates. Test result: positive

117 4.3.5 FCS - EVALUATION OF TEST RESULTS To date, field crews have not had any support in the form of an IT system providing information about the network and enabling communication with the dispatch centre. The purpose of the solution was to present in practice the ability to provide information to field crews. The implemented functionality provides basic information. The tests that are still underway are aimed at enabling an assessment of the effectiveness of support provided to field crews. Based on these first experiences, additional needs will be identified for the provision of support to field crews. 4.4 SCADA LV According to document D6.2, chapter 5.5, the main new features of LV SCADA included in particular: DER management, LV network topology management, FDIR for LV network, Transformers Management. In addition, the telecommunication layer is also included in the tests DER MANAGEMENT DER management functionality tests include: SCADA-001: Disconnect DER source from the network, SCADA-002: Connect DER source to the network, SCADA-009: Show information on der source connection options SCADA-001 DISCONNECT DER SOURCE FROM THE NETWORK Description: The purpose of the test is to verify whether or not is possible to turn off a DER source from SCADA Initial conditions: Operating DMS with active data acquisition. Operating SCADA with an active communication with DMS. DER source turned on. Steps: 1. Finding and turning off a defined DER source in SCADA Expected results: 1. After a maximum of 10 minutes, DMS will transmit to SCADA a new DER source status (turned off)

118 Results: The element representing the DER device was found on the map. Command was given to "Turn off" from the SCADA LV menu (Figure 55). FIGURE 55: SCADA LV - COMMAND TURN OFF DER The switch has changed status according to the command given. Change of status occurred, the information to SCADA reached ~ 6.5 minutes late (Figure 56)

119 FIGURE 56: SCADA LV - VISUALIZATION OF DER SHUTDOWN SCADA-002 CONNECT DER SOURCE TO THE NETWORK Description: The purpose of the test is to verify whether or not is possible to turn on a DER source from SCADA Initial conditions: Operating DMS with active data acquisition. Operating SCADA with an active communication with DMS. DER source turned off. Steps: Results: 1. Finding and turning on a defined DER source in SCADA Expected results: 1. After a maximum of 10 minutes, DMS will transmit to SCADA a new DER source status (turned on). The result of the performed test is positive. The element representing the DER device was found on the map. A command turn on was issued (Figure 57)

120 FIGURE 57: SCADA LV - COMMAND TURN ON DER The switch has changed status according to the command given. Change of status occurred, the information to SCADA reached ~ 6.5 minutes late (Figure 58)

121 FIGURE 58: SCADA LV - VISUALIZATION OF DER ACTIVATION SCADA-009 SHOW INFORMATION ON DER SOURCE CONNECTION OPTIONS Description: The purpose of the test is to verify whether or not is possible to obtain information about the current status of a DER source in SCADA Initial conditions: Operating DMS with active data acquisition. Operating SCADA with an active communication with DMS. DER source turned on. Steps: Expected results: Results: 1. Finding a defined DER source in SCADA 1. SCADA should present the current values of generated active power of a given DER. The result of the performed test is positive. The current value is 0W (Figure 59)

122 FIGURE 59: INFORMATION TRANSMITTED FROM A DER TO SCADA LV LV NETWORK TOPOLOGY MANAGEMENT LV network topology management functionality tests include: SCADA-010: Send LV network topology update, SCADA-011: Receive a LV network topology update SCADA-010 SENDING THE NETWORK STATUS. Description: The purpose of the test is to verify the correct operation of the network status sending mechanism (connector statuses and measurement values) from SCADA to DMS. Initial conditions: Operating SCADA with an active communication with DMS. Steps: 1. Select a SS 2. Select a fuse 3. Change the fuse status to the opposite. Results: Expected results: 1. Confirm receipt of the new fuse status in DMS. The result of the performed test is positive. The situation in both systems before changing the status of switches is presented in Figure

123 FIGURE 60: VISUALIZE THE NETWORK IN THE DMS LV AND SCADA LV BEFORE CHANGING THE CONNECTION The switch was turned off at the SS and closed in the LV cable cabinet. After sending state switches from SCADA LV to DMS LV, these switches were changed and correctly mapped (Figure 61)

124 FIGURE 61: VISUALIZE THE NETWORK IN THE DMS LV AND SCADA LV AFTER CHANGING THE CONNECTION SCADA-011 READING THE NETWORK STATUS. Description: The purpose of the test is to verify the correct operation of the network status receiving mechanism (connector statuses and measurement values with alarm thresholds) in SCADA from DMS. Initial conditions: Operating SCADA with an active communication with DMS

125 Steps: Results: 1. Find corresponding measurements in DMS and SCADA Expected results: 1. Both systems should display the same values. The result of the performed test is positive. View of SS in DMS LV was shown in Figure 62. View of SS in DMS LV was shown in Figure 63. Both systems share the same values. FIGURE 62: VIEW OF SS IN DMS LV FIGURE 63: VIEW OF SS IN SCADA LV

126 4.4.3 FDIR FOR LV NETWORK FDIR for LV network management functionality tests include: SCADA-004: Show short-circuit current detection notifications SCADA-005: Indicate the short-circuit area and switching sequence SCADA-006: Change switch state SCADA-007: Simulate the switching sequence SCADA-012: Short-circuit analysis request Due to the fact that SCADA LV does not have the ability to make network switches, "SCADA-008: Clear short-circuit current signaling activation" has not been performed SCADA-004 NOTIFICATION OF AN ACTUATED FAULT INDICATOR Description: The purpose of the test is to verify the correct operation of the mechanism for transmitting information about actuated fault indicators. Initial conditions: Operating SCADA with an active communication with DMS. Steps: 1. In SCADA, find an MV/LV SS with a fault indicator installed. 2. Simulate the activation of the fault indicator. Results: Expected results: 1. The fault indicator should be highlighted on the map in SCADA 2. The indicator status should be sent to DMS The result of the performed test is positive. An example of cable cabinet with active FPI is shown in the Figure

127 FIGURE 64: LV CABLE CABINET WITH ACTIVE FPI SCADA-005 RECEIPT OF A SEQUENCE OF SWITCHINGS AFTER THE OCCURRENCE OF A FAULT. Description: The purpose of the test is to verify the correct operation of the mechanism for transmitting information about actuated fault indicators. And receipt of the sequence of switchings in order to isolate the defective line section. Initial conditions: Operating SCADA with an active communication with DMS. Steps: Expected results: Results: 1. Continuation of the previous test 1. In response to the actuation of the fault indicator, DMS will prepare a plan of switchings to isolate the defective portion of the network. 2. The prepared plan should be sent to SCADA. 3. In SCADA, on the list of schematic operations, a new item should appear 4. From the context menu, the obtained sequence may be viewed and pertinent elements may be found on the map. The result of the performed test is positive. In SCADA, a pin appeared on the prepared sequence of switchings in the section between the cable cabinets Widna 7A staircase I and Widna 7C staircase III. From the context menu, it

128 was possible to go to the contents of the transmitted plan (Figure 65). FIGURE 65: VIEW OF THE TRANSMITTED PLAN IN SCADA LV SCADA-006 CONNECTOR STATUS CHANGE Description: The purpose of the test is to verify the correct operation of the connector status change mechanism. Initial conditions: Operating SCADA with an active communication with DMS. Steps: 1. Select any UPGRID connector 2. With a double-click or from the context menu, change the status to the opposite Results: Expected results: 1. The status of the element should be changed to the opposite. The result of the performed test is positive. The fuse status was changed correctly (Figure 66)

129 FIGURE 66: VIEW OF CONNECTOR STATUS CHANGE SCADA-007 SEQUENCE SIMULATION. Description: The purpose of the test is to verify the correct operation of the switching sequence viewing mechanism. Initial conditions: Operating SCADA with an active communication with DMS

130 Steps: 1. Select one of the previously sent switching plans 2. From the menu, execute the command Show a sequence simulation Results: Expected results: 1. A new network window will open in simulation mode with new object statuses. The result of the performed test is positive. From the context menu, the item "Show a plan of switchings" was selected, following which a window appeared with a list of proposed switchings. After clicking the Run a simulation button, a new window appeared with a map in simulation mode (blue background) and the statuses set as in the transmitted sequence (Figure 67). FIGURE 67: VIEW OF SEQUENCE SIMULATION SCADA-008 CLEARING THE NOTIFICATION OF AN ACTUATED FAULT INDICATOR. Description: The purpose of the test is to verify the correct operation of the fault notification clearing mechanism. The test may be carried out only in SCADA MV system, whereas the UPGRID system may not send any control commands. Initial conditions: Operating SCADA MV production system. Steps: 1. Find an activated fault indicator 2. From the map, run Clearing the fault indications Expected results: 1. Clearing the fault indications

131 Results: The test may be carried out only in SCADA MV system, whereas the UPGRID system may not send any control commands SCADA-012 REQUEST FOR PREPARING THE ISOLATION OF A SECTION Description: The purpose of the test is to verify the correct operation of the mechanism for requesting the preparation of a plan of switchings. Initial conditions: Operating SCADA with an active communication with DMS. Steps: 1. In SCADA, find a line section from the UPGRID project 2. Using the context menu, send a query about the plan of switchings Results: Expected results: 1. In response to the query, DMS will send back a plan of switchings. 2. On the list of schematic operations, a new operation should appear associated with the selected plan of switchings 3. From the context menu, a display of the plan of switchings may be executed and an element may be displayed on the map The result of the performed test is positive. For the selected section, a query was sent for a sequence of switchings.. In response, DMS transmitted a prepared sequence of switchings. A corresponding symbol was displayed in SCADA. From the context menu, it was possible to view the transmitted sequence (Figure 68). FIGURE 68: VIEW OF SEQUENCE OF SWITCHINGS IN SCADA LV

132 4.4.4 SCADA TELECOMMUNICATION LAYER In the telecommunications area, tests of data flow capacity were performed on a router enabling isolated transmission of data from SSs and the telemechanics controller. One of the constituent components of the pilot project is telecommunications infrastructure (devices together with services) for the purpose of communicating integrated AMI/Smart Grid cabinets installed in 48 MV/LV transformer SSs. This task was accomplished by providing infrastructure between SSs and EOP in the form of 48 routers with the data transmission service. For the purposes of the pilot project, 30 routers of one manufactures with two-way data transmission infrastructure from GSM Operator 1 were contracted and delivered along with 25 routers of other manufacturer with two-way data transmission infrastructure from GSM Operator 2. The general ICT infrastructure diagram is presented in Figure

133 AMI SCADA Router GRE/VPN AMI GRE/VPN SCADA EOP APN 3G/LTE SCADA Network R1 Transport network Operator 1 R1 APN CDMA APN UMTS CSO GW FW R2 R2 IP-Mobility Transport network Operator 2 APN CDMA GRE/VPN AMI AMI Network GRE/VPN SCADA FIGURE 69: TELECOMMUNICATION LAYER SCHEME FOR UPGRID PROJECT TESTING

134 The basic purpose of the tests was to establish communication with the Smart Grid controllers and AMI hubs in SSs in the UPGRID project. An additional purpose of the tests was the practical confirmation of the realized concept of telecommunications architecture, taking into account the security guidelines dedicated to the integrated AMI and Smart Grid solution. This concept is based on the following assumptions: separating out communication affected with the use of a shared communication medium (router with 2 Eth ports and an M2M service) for AMI and SCADA authentication, authorization and accountability of communicated devices (routers, SCADA controllers, AMI hub-and-balancing sets) using the 802.1x protocol and certificates encrypting communication using IPsec The tests were conducted jointly by the Telecommunications Department, the Risk and Security Systems Department and the device manufacturers, and consisted of the following stages: 1. Tests in laboratories of router manufacturers The tests resulted in the following findings: Routers of both manufacturers enable the establishment of encrypted transmission using IPsec in the PSK password option and with the encryption keys included in the certificate. Routers of Manufacturers 1 and 2 enable the setup of 2 independent IPsec tunnels to separate AMI and SCADA traffic on two Ethernet ports and a separate tunnel to the router. Routers of Manufacturers 1 and 2 enable a higher priority configuration for SCADA vis-à-vis AMI (the priority is assigned to the Ethernet port which forces appropriate connection of devices in the AMI/SG cabinet). In routers provided by Manufacturer 2, authentication is enabled using the 802.X protocol. In routers provided by Manufacturer 1, hardware limitations prevented the running of the 802.1X protocol. 2. Tests on MV/LV substations Due to the fact that: MV/LV substations selected for the UPGRID pilot project located in the Witomino area are within the AMI production infrastructure, terminal devices, i.e. controllers and hub-and-balancing sets are not equipped with the necessary functionalities, It was confirmed at this stage the achievement of such a configuration of devices that enables isolated communication for the AMI and SCADA production infrastructure. Tests of data flow capacity were performed for the routers provided by Manufacturer 2 and for the services provided by GSM Operator 2, the result of which was an assessment of the operation of

135 telecommunications links. On the basis of a 24-hour test and the obtained data (average data flow capacity and availability), the quality of 3GPP/CDMA links was evaluated (the results are presented in the test report). 3. Tests during controller prequalification procedures Routers provided by Manufacturer 2 for the UPGRID pilot project were used for controller prequalification. As a result of the tests carried out in a dedicated test environment prepared for this purpose, the following was confirmed: ability to download and route Performance Key Indicators (PKI) certificate controllers via the routers ability of authorization and authentication using the 802.1x protocol and EAP TLS in the supplicantclient-server configuration static and dynamic Local Area Network (LAN) configuration establishment of encrypted communication for SCADA using an IPsec protocol built on a PKI certificate, including the following two options: terminating IPsec tunnels for the router and router controller and terminating IPsec tunnels on the router and on the controller separately registration of controllers and update of names in the DNS Test results: positive EVALUATION OF TEST RESULTS The implemented SCADA LV solutions provided new opportunities for improving the efficiency of LV network management. The basis for the operation of SCADA LV is information obtained from GIS. A high quality of data in GIS is a basic requirement to enable the implementation of SCADA LV. Currently, the quality of data is insufficient. In the UPGRID project, it was necessary to carry out a time-consuming network inventory-taking. After the network inventory-taking, several verifications and data corrections were still necessary. In the UPGRID project, SCADA LV enabled the implementation of network management methods currently typical for MV networks. In the pilot area, a new level of real-time LV network monitoring was implemented. This monitoring is based on data obtained from AMI and own calculations. The developed solution requires further tests in the period remaining until the completion of the UPGRID project. Along with the development of microgeneration, active customer role and electro-mobility, in the LV network area SCADA will become an important element in supporting network traffic management. The experience gained in the UPGRID project will be taking advantage to develop recommendations for such solutions. The newly applied monitoring and control solutions were associated with the implementation of new solutions in the telecommunications layer. In the testing area, new routers purchased from two vendors

136 were verified. The tests were conducted on a new telecommunications layer prepared for the purposes of the UPGRID project. The implementation works and the tests of the two-way data transmission infrastructure, enabled the following: reconciliation of the production configuration of routers, reconciliation of the production configuration of controllers, reconciliation of requirements for firmware tests of hub-and-balancing sets, reconciliation of requirements in the specifications for the VPN hub, reconciliation of requirements in the specifications for the Radius functionality, in accordance with the telecommunication architecture concept and security guidelines. The positive test results and the improved security level resulted in using the experience gained in the UPGRID project and in implementing a new telecommunications layer in EOP. The tested solutions for new routers began to be implemented in EOP in They have now become standard in EOP. 4.5 INTEGRATION BETWEEN COMPONENTS AND EXTERNAL SYSTEMS - MODEL VALIDATION The network diagram showing the UPGRID project area was exported from SCADA to a CIM RDF XML file. As a result, a file of approx. 60MB was created. To validate the network diagram, the Cimphony Orchestra software provided by the British company Open Grid Systems was used. This software enables, without limitation: validation of input data in CIM format download and edition of network diagrams in formats such as CIM RDF XML, Multispeak, PSS/E, IEC61850 visualization of the network diagram on background maps execution of power flow calculations Validation of the file containing the network diagram in CIM RDF XML format takes place when the file is loaded into Cimphony. This method of validation of a file named Mikronika_11A17h.xml in CIM RDF XML format containing the network diagram of the UPGRID project area resulted in presenting the information depicted in Figure

137 FIGURE 70: CIM RDF XML FILE VALIDATION RESULT. The presented information about the validation errors for the file containing the network diagram resulted in the following: Different versions of the CIM model based on which the validation was executed this concerns the errors related to Terminal.sequenceNumber, rateds.multiplier and rateds.unit. Imperfections of the engine which exported the CIM model this concerns the errors related to ObjectNotFoundException. The errors that were found will probably be removed in the final version of the CIM RDF XML file containing the network diagram. They do not affect the correct transmission of the network diagram between SCADA and the demonstration system. After the network diagram validation is completed, each CIM model object is displayed along with the quantity in which it appears in the diagram, as presented in Figure

138 FIGURE 71: CIMPHONY WORKSPACE WITH VALIDATED CIM RDF XLS INPUT FILE OBJECT BROWSER. It is also possible to display the CIM RDF XML file containing the diagram in text format, directly from Cimphony, as presented in Figure 71. FIGURE 72: CIMPHONY WORKSPACE WITH VALIDATED CIM RDF XLS INPUT FILE TEXT BROWSER

139 CIM network schematics validation process aided by Cimphony software package allows for efficient identification of possible RDF XML file semantic errors and their elimination. Performed validation of the file containing network schematics for project area showed a few errors in fact not affecting the scope of exchanged data and its correctness. Using Cimphony allowed for further examination of the network schematics file, especially classes and attributes of network objects within the project area. 4.6 ALGORITHMS FOR REALIZATION OF DMS LV FUNCTIONS CALCULATING POWER DISTRIBUTION The load flow function is intended to show the state of low voltage grid. As the result of this function run, the following parameters are determined: Nodal voltage modules, Currents flowing through the line sections, Active power losses of the line sections, Sum of active power losses resulting from the all line sections. The correct operation of the load flow function has been confirmed by verification tests, where the values calculated in the implemented algorithm are compared to the values derived from the reference model. The reference model was implemented in the PowerFactory software from DIgSILENT. Because the implementation of the load flow algorithm was performed by the ATENDE Software and the verification on model performed by Gdansk University of Technology, the tests preceded verification of the grid common model used to comparison of purpose. In addition, the computing time of the load flow function was also assessed. The test was divided into several stages, including inter alia: acquisition of measured data (energies) from the customer meters, estimation of missing measurement data and execution of the load flow calculations. AMI system efficiency in acquisition of the measured data from the customer meters was also tested. The goal was to check how much time it takes to acquisition enough measured data to get acceptable results. It was assumed start of the load flow function run after from time of the load measure by the customer meters: 15 min, 1 h, 6 h, 12 h, 24 h, 48 h

140 COMPARISON OF RECEIVED VALUES FROM AN IMPLEMENTED ALGORITHM WITH VALUES RECEIVED FROM THE REFERENCE MODEL The following test aim was to validate the implementation of the load flow algorithm by comparing selected results obtained from implemented algorithm and the reference model. The test was made for the LV grid being supplied from Mitrowa substation (Fig. 73), for 4 selected measurement times (periods): :45, :45, :45 and : m line type line type line type line type line type line type line type line type line type line type FIGURE 73: LV GRID SUPPLY FROM MITROWA SUBSTATION. REFERENCE MODEL Comparison of the results obtained was made using the following equation: 1 Vcalc/Vref *100% The test results are presented in Tables 13 to 16. It should be noted, that the results obtained from the implemented algorithm are highly convergent with the results obtained from the reference model

141 TABLE 14 VOLTAGE OF NODES. LV GRID SUPPLY FROM MITROWA SECONDARY SUBSTATION Node name (the beginning and the end of the line section), date, hour Vcalc [V] Calculated voltage Vref [V] Voltage from reference model 1 Vref/Vcalc [%] Difference between calculated and reference values Acceptable (Yes/No) ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes

142 TABLE 15 LINE SECTION CURRENT. LV GRID SUPPLY FROM MITROWA SECONDARY SUBSTATION Line section name, date, hour From To Icalc [A] Calculated current Iref [A] Current from reference model Iref/Icalc [%] Difference between calculated and reference values Acceptable (Yes/No) ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes

143 ABLE 16 ACTIVE POWER LOSSES IN LINE SECTIONS. LV GRID SUPPLY FROM MITROWA SECONDARY SUBSTATION Line section name, date, hour From To Pcalc [kw] Calculated power loss Pref [kw] Power loss from reference model Pref/ Pcalc [%] Difference between calculated and reference values Acceptable (Yes/No) ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/01,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/07/15,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/01,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes ,2017/08/15,20:45: Yes

144 TABLE 17 SUM OF ACTIVE POWER LOSSES. LV GRID SUPPLY FROM MITROWA SUBSTATION Grid name, date, hour Pcalc [kw] Calculated sum of power losses Pref [kw] Sum of power losses from reference model Pref/ Pcalc [%] Difference between calculated and reference values Acceptable (Yes/No) 2758,2017/07/01,20:45: Yes 2758,2017/07/15,20:45: Yes 2758,2017/08/01,20:45: Yes 2758,2017/08/15,20:45: Yes IMPACT ASSESSMENT OF MEASURED DATA ACQUISITION TIME ON LOAD FLOW RESULTS The goal of the test was the verification of how the start time of the load flow function runs (counting from the time of the measured data by customer meters store in the meter) influences on the results of the load flow calculations. The following times are taken into consideration: 15 min., 1 h, 6 h, 12 h, 24 h, 48 h. The test was conducted for the Mitrowa substation and for the Witomino area. Twelve time periods were considered: six for Wednesday ( ) and six for Sunday ( ). In both cases these were example hours: 00:00, 03:00, 07:00, 11:00, 15:00, 20:00. The following test does not include estimates of the missing measurements. This means that the load flow calculations are based only on measurements that arrived to AMI system at a defined time. Table 18 and Table 19 show the voltages and currents of the LV grid being supplied from Mitrowa substation as results of the load flow calculations. Additional results are shown for the measurement data available on the test day ( ), that means that the waiting time for the measured data was over month. TABLE 18 VOLATGE OF NODE. LV GRID SUPPLY FROM MITROWA SECONDARY SUBSTATION Node name, date, hour V15min [V] V1h [V] V6h [V] V12h [V] V24h [V] V48h [V] Vcurrent* [V] , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00:

145 Node name, date, hour V15min [V] V1h [V] V6h [V] V12h [V] V24h [V] V48h [V] Vcurrent* [V] , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00:

146 Node name, date, hour V15min [V] V1h [V] V6h [V] V12h [V] V24h [V] V48h [V] Vcurrent* [V] , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00: , :00:

147 Node name, date, hour V15min [V] V1h [V] V6h [V] V12h [V] V24h [V] V48h [V] Vcurrent* [V] , :00: , :00: , :00: , :00: , :00: , :00: , :00: * current data available on the test day: TABLE 19 LINE SECTION CURRENT. LV GRID SUPPLY FROM MITROWA SECONDARY SUBSTATION Line section name, date, hour I15min I1h I6h I12h I24h I48h [A] [A] [A] [A] [A] [A] , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00:

148 Line section name, date, hour I15min I1h I6h I12h I24h I48h [A] [A] [A] [A] [A] [A] , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00:

149 Line section name, date, hour I15min I1h I6h I12h I24h I48h [A] [A] [A] [A] [A] [A] , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: , , 00:00: , , 03:00: , , 07:00: , , 11:00: , , 15:00: , , 20:00: Figures from Figure 74 to Figure 79 show the difference between voltage calculated based on measured data available on test day ( ) and voltage calculated for the selected period time i.e.: 15 min, 1 h, 6 h, 12 h, 24 h i 48 h. The following Figures (and the Table 18) show that in period times 15 min, 1 h and 16 h, in many cases a large difference between voltages. Acceptable results, i.e. small voltage difference, are only obtained for the measurement data that arrived up to 12 h. In this case, the difference does not exceed 0.2 V, usually

150 V actual -V 15min [V] PPE [-] FIGURE 74: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO 15 MIN V actual -V 1h [V] PPE [-] FIGURE 75: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO 1 H V actual -V 6h [V] PPE [-] FIGURE 76: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO 6 H

151 V actual -V 12h [V] PPE [-] FIGURE 77: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO V actual -V 24h [V] PPE [-] FIGURE 78: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO 24 H V actual -V 48h [V] PPE [-] FIGURE 79: VOLTAGE DIFFERENCE BETWEEN MEASURED DATA CURRENT AND AVAILABLE UP TO 48 H Figures from Figure 80 to Figure 84 show the difference between the current values calculated for measured data obtained up to 48 h and measured data obtained up to 15 min, 1h, 6 h, 12 h and 24 h from the time of customer meters store the measured value. The results are consistent with the results

152 obtained for the voltage. Acceptable differences between the current values are obtained for measured data that arrived up to 12 h and more from the time of measurement (Figure 83 and Figure 84). I 48h -I 15min [A] line x time [-] FIGURE 80: LINE SECTION CURRENTS DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 15 MIN. MITROWA SECONDARY SUBSTATION I 48h -I 1h [A] line x time [-] FIGURE 81: LINE SECTION CURRENTS DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 1 H. MITROWA SECONDARY SUBSTATION I 48h -I 6h [A] line x time [-] FIGURE 82: LINE SECTION CURRENTS DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 6 H. MITROWA SECONDARY SUBSTATION

153 I 48h -I 12h [A] line x time [-] FIGURE 83: LINE SECTION CURRENTS DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 12 H. MITROWA SECONDARY SUBSTATION I 48h -I 24h [A] line x time [-] FIGURE 84: LINE SECTION CURRENTS DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 24 H. MITROWA SECONDARY SUBSTATION The above test was also carried out for the entire Witomino area. The voltage and current differences are shown in Figures from Figure 85 to Figure 89. The presented results show that (unlike the results for Mitrowa SS) for the calculation based on the measured data available up to 12 h, there are many nodes where the voltages differ by several volts (from 1 V to 7 V). Only in case when the measured data are available up to 24 h, less voltage difference (1 V) has been achieved

154 WP6 - DEMONSTRATIONS IN REAL USER ENVIRONMENT: ENERGA - POLAND a) b) I48h-I15min [A] V48h-V15min [V] node x time [-] node x time [-] FIGURE 85: VOLTAGES (A) AND CURRENTS (B) DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 15 MIN. WITOMINO AREA a) b) I48h-I1h [A] V48h-V1h [V] node x time [-] node x time [-] FIGURE 86: VOLTAGES (A) AND CURRENTS (B) DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 1 H. WITOMINO AREA a) b) I48h-I6h [A] V48h-V6h [V] node x time [-] node x time [-] FIGURE 87: VOLTAGES (A) AND CURRENTS (B) DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 6 H. WITOMINO AREA

155 WP6 - DEMONSTRATIONS IN REAL USER ENVIRONMENT: ENERGA - POLAND b) I48h-I12h [A] V48h-V12h [V] a) node x time [-] node x time [-] FIGURE 88: VOLTAGES (A) AND CURRENTS (B) DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 12 H. WITOMINO AREA b) I48h-I24h [A] V48h-V24h [V] a) node x time [-] node x time [-] FIGURE 89: VOLTAGES (A) AND CURRENTS (B) DIFFERENCE BETWEEN MEASURED DATA AVAILABLE UP TO 48 H AND UP TO 24 H. WITOMINO AREA The convergence of the load flow calculation to the reality is closely related to the availability of the measured data in AMI system. The increase of accessible data at a given time means higher convergence of the results of calculations to reality. ENERGA-Operator s data acquisition technology (PLC) is characterised by long time of the measured data acquisition (the time increase with the electrical distance from meter to the concentrator) increases. This means that only a very few measurements can arrive in few minutes (expected period of time), but this does not allow for proper representation of network state. Figure 90 shows an example of acquisition efficiency of the measured data for Mitrowa SS. It appears that for this SS, even after waiting time more than a month, the data are not available in 100%. However, there are periods of time for which more than 80% of measurements are available after 15 minutes ( :00:00, :00:00 i 07:00:00). But there is also a periods of time ( :00:00) for which only slightly more than 50% of the measured data are available, up to 12 h

156 The tests do not allow to identify the reasons for various number of measured data availabilities for various periods of times. A reason of that is too small number of the analysed measured data. Therefore, it cannot be concluded that there is correlation between day type (work or holiday day), measurement time, and acquisition speed of the measured data as a reason of the problem. responded meters / all meters [%] % 90.00% 80.00% 70.00% 60.00% 50.00% 40.00% 30.00% 20.00% 10.00% 0.00% :00: :00: :00: :00: :00: :00: :00: :00: :00: :00: :00:00 20:00:00 15min. 1h 6h 12h 24h 48h actual FIGURE 90: NUMBER OF METERS THAT REPLY IN ASSUMED TIME. MITROWA SUBSTATION EVALUATION OF THE LOAD FLOW FUNCTION COMPUTING TIME Assuming some simplifications, the load flow function computing time can be divided into four steps: Measured data (energy) collection from the customers meters, Estimation of the missing measurements, Load flow calculation, Visualization of the calculation results in SCADA system. The way of measuring by the customers meters data collection has been discussed above. The discussion shows that the time used for the data collection in some cases can be very long. The presented example shows that, even during 1 month, the whole data has not been collected from Mitrowa SS. But, from another side, there are periods of time during a month in which, even after 15 minutes from the sent request for the measured data, above 90% of the measurements is accessible. This shows that the process of the measurements collection is relatively long and can typically take from few up to several hours. In such cases, i.e. lack of complete set of measurements, the rest of measurements has to be estimated. The discussed test allows to evaluate the time needed for the load flow calculation. The test has been carried out for a single SS (Mitrowa) and for the whole Witomino area (demonstrator area). The test results are presented in Table

157 Time TABLE 20 TIME OF POWER FLOW FUNCTION EXECUTION tlfcalc [s] Time of power flow calculation execution. Mitrowa SS. tlfcalc [s] Time of power flow calculation execution. Witomino area :00: :00: :00: :00: :00: :00: The table presented above shows that the load flow function computing time is very short, and for the Witomino area (demonstrator area) is less than 1 second COMPARISON OF THE MEASURED (AMI METERS) AND CALCULATED VOLTAGES The idea of the load flow function is to represent the state of the low voltage network for the test network and to present this state, in the form of the nodal voltages and the branch currents, to the SCADA user. The specificity of the solutions that exist at the EOP operator enforces to perform the load flow calculations on a symmetrical model of the grid. This is mainly due to lack of knowledge of the operator to which phase is connected a given single-phase counter. Also the phase sequence for the three-phase meters is unknown. This makes that power (load), at a given load, is just calculated as the sum of the measured powers and next is treated as the 3-phase symmetrical load. This is the simplification that can have high negative influence on the calculations results. The resulted voltages in the grid, i.e. result of the load flow function use in such form, can be treated as the average nodal voltage values. The purpose of this test is to check the deviations from the values measured by the customers meters (the energy is measured and recalculated into power) and calculated by the load flow function. The test was conducted for the entire Witomino area, for two selected days (Wednesday and Sunday ) and the six measurement periods: 00:00, 03:00, 07:00, 11:00, 15:00, 20:00. Due to the large number of results obtained, only the analysis of these results is presented in the form of appropriate drawings. The table structure and exemplary results are shown in Table 21, where the following columns indicate: Node name, date, hour node number (beginning and the end of the line section), date and time of measurement done by the customer meters. Vcalc voltage calculated by the load flow function. VMIN, VMAX Minimum and maximum voltage from the three phase-neutral voltages collected from the customers meters at a given node. Vdev Percent difference between voltages calculated and measured, while the measured value is here a mean value of the three phase-neutral voltages

158 TABLE 21 NODE VOLTAGE. WITOMINO AREA. MEASUREMENT DATA AVAILABLE UP TO 1 H Node name(the beginning and the end of the line section), date, hour Vcalc [V] Calculated voltage VMIN, VMAX [V] Min and max voltage chosen from three phases of meters Voltage is in range Min Max (Yes/No) Vdev [%] Difference between calculated and measured voltages (arithmetic mean of 3 phases) , :00: ; No , :00: ; Yes , :00: ; No , :00: ; No , :00: ; Yes , :00: ; Yes 0.35 In the test they were used the measurement data available in the AMI system after 1 hour after the measurements have been recorded by the customers meters. This led to state that the voltages were not available for each node in the grid, in the considered case the nodal voltages were accessible only for 45.8% of the nodes. This value should not be treated as the number of meters from which the measurement data was received, because usually more than one meter is connected to a given node. Hence the percentage of the meters that responded within 1 hour may be less than in the presented example. In the presented case there are considered only those nodes for which the voltage measurements were available. A measure indicating that the results obtained from the power flow can be considered as acceptable is the placement of the value calculated for a given node between the minimum and maximum values obtained from the measurements for that node. In the case under consideration, only for 22.5% of nodes the calculated voltages are located between the minimum and maximum values. This does not necessarily mean that in the other cases (value of voltage outside the range of Min Max) the calculated voltage values differ highly from the values taken from the meters. On the other hand, some uncertainty remains in the situation where the minimum and maximum values are equal while the calculated value is different. In general, it may mean that, in such node, only single-phase meter(s) is (are) connected or the measured data came from a single meter only. To clarify this, we need information about the number of meters connected to the node and about their type (one or three phases). Such hard verification cases are 17.6% in the presented example. In turn, in 59.6% of nodes, the voltage computed locates outside the voltage range limited by the minimum and maximum values. Again, it does not mean that these measurements are far from reality. There may be cases in which, for example, the minimum and maximum values differ slightly and the value calculated in the load flow also slightly differs from that range. Another measure used here to check how the calculated values deviate from the real values is comparison of the calculated values to the arithmetic mean of the real three phase-neutral nodal voltages (Figure 91). The test results show that for about 75% of cases the difference is in the range of 0% to 2%. and in about 90% of the cases ranges from 0% to 3%. What can be treated as positive value

159 a) b) V dev [%] measurements [%] = >20 measurement [-] V dev [%] FIGURE 91: DIFFERENCE BETWEEN CALCULATED VALUE AND MEAN VALUE CALCULATED FROM MEASURED VOLTAGES (A), AND MEASUREMENTS NUMBER IN VDEV FUNCTION (B) Summing up the tests related to load flow calculation function, it should be noted that the results obtained from the load flow function highly depend on time between the measurements (taken by the customers meters) and the load low function run. This is especially crucial in case of the missing data existence and lack of the missing data estimation. It is assumed that the calculated values that are close to the real values can be calculated using the measured data that will come to the AMI system within 24 hours. At the same time, it should be remembered that the values obtained from the load flow are subject to errors, which will be affected mainly by: Inclusion only active power in calculations. Calculation of the instantaneous power from the energy measured. Summing up of the active powers measured by meters connected to a given node. Lack of exact synchronization of the customers counters. The counters are synchronized by the concentrator which sends the current time to the meters. This means that the dispatcher in practice cannot use online the load flow function, for current operation of the grid control, because he cannot get information about current state of the grid, i.e. about voltages and currents, online. However, the function can be used for the historical events analysis and for the planning purposes. Further works related to the load flow function should be focused on the increase of the measured data collection effectiveness, i.e. on minimization of the time needed for collecting sufficient amount of data, allowing to get on line reliable load flow. Secondly, the works have to be focused on the lacking (missing) data estimation process speeding up, even at the expense of the accuracy of the obtained results

160 4.6.2 FORECASTING LOADS AND DISTRIBUTED GENERATION The energy readings from customers meters are used for load flow calculation function. Firstly, it was assumed, that load flow calculation will be executed in 15 minutes intervals, using the readings obtained 15 minutes earlier. The carried out tests revealed that in 15 minutes only a part of readings is available in AMI system. Therefore, the rest of the readings has to be estimated. An estimation algorithm for load forecasting was tested on 2000 randomly chosen meters. During the test a single reading for specified time stamp was erased and then it was estimated. For estimation two different time ranges of historical data were used (7 days and 30 days) and different time displacement between estimated readings and historical readings (1 day, 7 days, 10 days and 30 days). The test results are presented in Figure 92 to Figure day A+ 7 days A+ 10 days A+ 30 days A+ 1 day A+ 7 days A+ 10 days A+ 30 days A forecasting accuracy [%] forecasting accuracy [%] meters [-] meters [-] FIGURE 92: DIFFERENCE BETWEEN ESTIMATED AND REAL VALUES. LIMITED TO 1000% (A) AND 100% (B). ESTIMATION WITH 7 MEASUREMENT DAYS 1 day A+ 7 days A+ 10 days A+ 30 days A meters [%] = >1000 forecasting accuracy [%] FIGURE 93: METERS NUMBER FOR WHICH DIFFERENCE BETWEEN ESTIMATED AND REAL VALUES LOCATES IN ASSUMED RANGE. ESTIMATION WITH 7 MEASUREMENT DAYS

161 1 day A+ 7 days A+ 10 days A+ 30 days A+ 1 day A+ 7 days A+ 10 days A+ 30 days A forecasting accuracy [%] forecasting accuracy [%] meters [-] meters [-] FIGURE 94: DIFFERENCE BETWEEN ESTIMATED AND REAL VALUES. LIMITED TO 1000% (A) AND 100% (B). ESTIMATION WITH 10 MEASUREMENT DAYS 1 day A+ 7 days A+ 10 days A+ 30 days A meters [%] = >1000 forecasting accuracy [%] FIGURE 95: METERS NUMBER FOR WHICH DIFFERENCE BETWEEN ESTIMATED AND REAL VALUES LOCATED IN ASSUMED RANGE. ESTIMATION WITH 10 MEASUREMENT DAYS According to presented results, the best accuracy is achieved when time displacement between estimated readings and historical readings is one day. Then estimation error is less than 5% for 70% of meters, and estimation error is less than 10% for 80% of meters. The time range of historical data (7 days and 30 days) does not influence on estimation error. The estimation time is a certain problem. The estimation time for a single meter varies from 0.6 s to even 20 s, and it depends on historical data availability. The tests reveal that in 15 minutes time only a part of meter readings will be available. Assuming 50% data availability the time for estimation of remaining meters in Witomino area (14687 meters) will exceed couple of hours (for the fastest estimation time of single meter equal to 0.6s). It should be noted that, estimation of customers meter readings is a very difficult task when customer power demand is highly improbable. The test results lead to conclusion that estimation of meter readings is justified only when the amount of meter readings available in AMI is large, i.e. speed of meter readings to AMI system is improved

162 4.6.3 FORECASTING TRANSFORMER TEMPERATURE Forecasting transformer temperature algorithm was implemented in DMS system. Until report submission the temperature measurements of real transformer are not finished, due to procedural considerations. The measurements will allow for algorithms validation and tuning its parameters. In addition to the scheduled tests at the transformer SS owned by EOP, the tests are also carried out on transformer in research laboratory LINTE^2, at Gdansk University of Technology. The decision on carrying out test in laboratory results from the possibility of testing of dry type-transformer instead on oil immersed transformer installed in Witomino area. In addition, the performing of laboratory tests is procedurally far easier than on a real network

163 5 CONCLUSIONS The Polish demonstration area realized as part of UPGRID WP6 integrated the following two areas: new prototype solutions for LV network monitoring and control and new functionalities of IT systems. In the IT systems, new functionalities were implemented based on the integration of data from the systems used by the DSO. The data that were used had been obtained from smart meters (AMI system), network monitoring devices (SCADA system) and GIS as well as network failure information from the network management support system. The improved UDP system solution provided a new functionality for customers, providing them with the ability to evaluate the effects of DER usage. Also at the device level, integration was an important component. It enabled a reduction in the costs of constructing SSSs. At the same time, solutions for SSs also provided additional data from MV and LV network monitoring systems. The newly applied SS monitoring and control solutions were implemented and developed alongside the implementation of new solutions in the telecommunications layer. 5.1 SMART SECONDARY SUBSTATIONS The UPGRID project is of key significance to EOP for the development of monitoring and control in SSs. In the project, the experience gained in the following two areas was taken advantage of: Automation of SSs. EOP has been developing the network automation area in recent years as an important element in its striving toward improving the continuity of supply and reducing SAIDI and SAIFI, AMI infrastructures. New solutions have been developed to integrate these previous areas. As a result of the work performed under the project, along with the construction and testing of prototypes, new solutions have been created featuring: Lower costs of production, installation and operation, Improvement in the SS monitoring level by including additional current and voltage measurements in MV and LV networks, Separation (rather than duplication) of a number of devices used, Improvement in the level of cyber-security through applying new solutions in the telecommunications layer, Development of relatively low-cost solutions to monitor SSs without remotely controlled MV switchgear (SSs in service, older types), Extension of the scale of SS monitoring to include all SSs, including those currently in service. The completed tests of prototype solutions demonstrated their effectiveness and efficiency. The test findings have been taken advantage of by EOP in its SS monitoring and control standard. In 2017, the standard for SSSs was adopted by EOP. New solutions are currently implemented and by 2020 as much as 90% of all SSs will operate under one of the SS monitoring and control options

164 5.2 NEW FUNCTIONALITY OF IT SYSTEMS The implemented IT solutions are based on EOP s existing systems and are rooted in their functionalities: DMS LV a solution based on the AMI production system, SCADA LV a solution based on the SCADA MV production system. However, it was of key significance to build new functionalities utilizing information from both network monitoring devices and smart meters. Previously, smart meters were merely a source of data for billing systems and customer support systems. They were not used for network operation and asset management. When the UPGRID solutions were being built, strong emphasis was put on the use of data obtained from AMI for monitoring of SSs. Before the UPGRID project, monitoring in these SSs was limited to information about the flow of fault currents in the MV portion of the network. In the UPGRID project, data were used from the AMI infrastructure to monitor electricity parameters on the LV side. New near real-time (approx. a 15-minute time lag) DMS LV monitoring functions provide information to SCADA LV. Further analysis is required in respect of verification of the amount of data transmitted and the possibility of implementing such solutions throughout a LV network equipped with smart meters. For the first time, functionalities were built using data from the PLC telecommunications layer. Algorithms analyzing communication problems with smart meters have been deployed and are being developed. Based on such analysis, potential places with a permanent loss of connectivity are identified locations of potential failures in the LV network. Data on such places are transmitted to SCADA LV and are visualized on maps depicting the LV network. This is the first step toward using AMI to identify the locations of failures in the LV network. Further studies and tests (with test reconnections in the network) and analysis of actual failures will be used to optimize the algorithms. Figure 96 presents a sample SCADA LV display in which a portion of the network is marked with pins indicating the locations of a possible failure

165 FIGURE 96: SCADA LV MAP VIEW WITH ALARMS (INFORMATION ABOUT PROBABILITY OF FAILURE IN LV NETWORK) This newly developed solution may have a much broader range of applications. Similarly, places may be searched for and analysis where problems in communication occur between the smart meters and the hubs. The system functionalities support in particular: Improvement in the quality of electricity supply (by shortening interruptions), Maintenance of a high quality of supplied electricity, Provision of effective support for network traffic management and operation, Reduction in network losses. It was of key significance for the project a tool that would enable the provision of direct support to customers. The newly developed solution provides customers with knowledge about potential PV installation opportunities and the effects that such installation will have on the individual electricity consumption by the customer. 5.3 QUALITY OF DATA AND DATA MANAGEMENT The IT systems that have been implemented in the demonstration area, namely DMS LV and SCADA LV, are based on data obtained from the GIS and AMI systems. These are the primary data sources. In order to be able to make use of data to manage network traffic, the data must be of very high quality. Previously, data on the LV network obtained from GIS were used mainly to manage network assets. The quality of such data is gradually being improved to satisfy the needs of network operation. The experience gained in the UPGRID project suggests that a much higher quality of data is required for systems that support network traffic management. Full data about the LV network are necessary,