Synchrophasor Applications on Brazilian Interconnected System International Conference on Phasor Measurements Applications June, 2006 Rui Menezes de Moraes Héctor Andrés Rodriguez Volskis
Introduction Historical overview 2
Historic Studies for PMU application on the Brazilian electrical system, mainly for dynamic performance registering during disturbances, was started by the Subcommittee of Electrical Studies (SCEL), part of the Group for the Coordination of Interconnected Operation (GCOI), in the beginning of the 90 ths Difficulties faced by Brazilian economy during that decade and the reorganization of the electric energy sector delayed the project until 1999 In 26 of August of 1998 ONS was created with the role of the National Interconnected System - NIS operation The huge blackout occurred in 11 March, 1999, revived the interest in PMU application It was necessary to spent some time to obtain the adequate regulatory framework 3
Regulatory Framework 4
ANEEL s Resolution ANEEL is the Brazilian Electrical Energy Regulatory Agency Authoritative Resolution ANEEL-170, may/2005 Utilities responsibility The utilities should acquire, install, operate and maintain the PMU placed in theirs substations. They also should provide the communication links to Central Phasors Concentrator at ONS, obeying technical requirement, specification and timeline defined by ONS Financial feasibility The costs of equipments and activities will be considered by ANEEL in the revision of tariffs or service s costs. Tariffs and costs are reviewed each four years 5
ANEEL s Resolution ONS s responsibility To review Phasor Measurement System's architecture and telecommunication requirements To specify, acquire and install the ONS s Central Phasors Concentrator To review the requirements, the quantity and placement of the PMU to be installed in utilities substations To coordinate PMU s certification through adequate tests to guarantee the systemic performance To define the timeline and coordinate PMU installation by utilities 6
7 National Interconnected System (NIS) Phasor Measuring Project
ONS s initiatives Projects included in ONS s Action Plan (2006-2008) Off-line applications: Project 6.2 Implementation of Long Duration Recording System Project s main objective is to implement a PMU system to record the NIS s dynamic performance during wide area disturbances Real-time applications: Project 11.11 Application of PMU Technology to Support Systems in Real Time Decision Making Project s main objective is the use of PMU measures for realtime applications, mainly state estimation enhancement 8
Phasor Measuring System What do we want? To increase SIN reliability using synchrophasors measuring technology to dynamic disturbance recording, real-time monitoring and state estimation enhancement How is this project being conducted? With a top-down approach With shared responsibility among ONS and Utilities With focus on global synchrophasor system performance To use different PMU suppliers (open-system approach) Needs the specification of system architecture, PMU, PDC and communication functional requirements 9
Phasor Measuring System Which applications would we like to have? Dynamic disturbance data recording - post disturbance analysis (including modal frequency analysis) Dynamic model & controllers settings validation Out-of-step protection monitoring and transmission line parameters measuring (On main interconnections) Real-time data monitoring & event prediction (Visualization tools at ONS Control Center) State Estimation enhancement Introduce phasor measurements in EMS 10
Phasor Measuring System Do ONS intend to use synchrophasors to control and protection? Not right now If possible, system architecture should not limit control and protection applications in the future 11
Phasor Measuring System Off-line applications Project 6.2 12
First PMU placement studies 13
PMU Placement Criteria System studies Characteristic inter-area and local oscillation modes Frequency range limited to 1Hz Three load flow scenarios (heavy, medium and light) Three interchange conditions in North-South Interconnection (+1000MW, no interchange) Interconnections with out-of-step tripping protection 14
Oscillation Modes (Hz) HEAVY LOAD MEDIUM LOAD LIGHT LOAD # N-S 1000 MW N-S ZERO S-N 1000 MW N-S 1000 MW N-S ZERO S-N 1000 MW N-S 1000 MW N-S ZERO S-N 1000 MW SUB-SYSTEMS INVOLVED 1 0,18 0,18 0,18 0,16 0,13 0,19 0,19 0,19 0,23 N-NE X S-SE 2 0,49 0,50 0,50 0,47 0,50 0,52 0,55 0,57 0,59 (SOUTH + ITAIPU) X SOUTHEAST SYSTEM 3 0,51 0,51 0,51 0,52 0,51 0,49 0,45 0,45 0,45 SERRA DA MESA X SIN 4 0,60 0,57 0,64 0,58 0,66 0,71 0,66 0,69 0,72 TUC+B.ESPER+S.MESA X SIN 5 0,73 0,72 0,74 0,77 0,77 0,83 0,83 0,82 0,87 CESP X SIN 6 0,77 0,77 0,77 0,77 0,77 0,77 0,84 0,84 0,84 SOUTH SUB-SYSTEM X SIN 7 0,88 0,89 0,89 0,88 0,87 0,88 0,92 0,91 0,91 PARANAÍBA RIVER S PLANTS X SIN 8 0,91 0,92 0,91 1,00 1,00 1,00 0,97 0,96 0,97 LOCAL MODE CESP N.AVANHANDAVA +PROMISSÃO 9 0,95 0,95 0,95 0,99 0,99 0,99 0,93 0,94 0,97 LOCAL MODE CEEE JACUÍ Ref.:1999 15
First PMU Placement SUBSTATION VOLTAGE (kv) OWNER 29 substations TUCURUÍ IMPERATRIZ 500 500 ELETRONORTE ELETRONORTE PRESIDENTE DUTRA 500 ELETRONORTE BOA ESPERANÇA 500 CHESF PAULO AFONSO 500 CHESF FORTALEZA 500 CHESF CAMAÇARI 500 CHESF MIRACEMA 500 ELETRONORTE SERRA DA MESA 500 FURNAS SAMAMBAIA 500 FURNAS ITUMBIARA 500/345 FURNAS SÃO SIMÃO 500 CEMIG JAGUARA 500/345 CEMIG FURNAS 345 FURNAS MARIMBONDO 500/345 FURNAS ADRIANÓPOLIS 500/345 FURNAS CACHOEIRA PAULISTA 500 FURNAS ÁGUA VERMELHA 440/500 CTEEP ILHA SOLTEIRA 440 CTEEP JUPIÁ 440 CTEEP BAURÚ 440 CTEEP ITABERÁ 765 FURNAS TIJUCO PRETO 765/500/345 FURNAS IVAIPORÃ 765/500 FURNAS/ELETROSUL IBIUNA 345 FURNAS FOZ DO IGUAçÚ 765 FURNAS AREIA 500 ELETROSUL ITÁ 500 ELETROSUL GRAVATAÍ 500 ELETROSUL 16
PMU placement revision 17
Revised PMU Placement 37 substations 18
19 PMU Placement
Phasor Measurement System Architecture Design KEMA Proposal 20
PMS Requirements For off-line applications: Reliable data acquisition and archiving, no hard time limit to meet Current placement studies calls for 37 substations, with near 230 circuits (measuring positive voltages and currents) For real-time applications: To meet the overall latency time, preliminarily set to 2 seconds The number of PMU may increase considerably For overall system: It must be scalable Cyber security must be considered 21
22 PMS Overall Architecture
PMS Proposed Architecture Two Central Data Concentrators (CDC) located in different ONS' Control Centers To provide data safety in case of hardware or software failure Two options for Agents' control center level Agent Phasor Data Concentrator is optional Two options for Agents' substation level A substation data backup device allows comply with failures in communication channels A substation Phasor Data Concentrator for PMU data aggregation and bandwidth optimization may be used where needed Telecommunications requirements Dedicated communication channels should be used for bandwidth guarantee and system security Real-time Phasor Data will be sent in UDP/IP format with multicast IP addressing Network routers and switches should be capable to handle multicast IP packets To be possible to make a direct connection from substation to ONS CDC 23
24 Substation Level Architecture
Substation Level Architecture Phasor Measure Units (PMU): Will send real-time data in C37.118 format using multicast IP addressing Data will be routed to two destinations: To Agents Control Centers or ONS Control Center To the Substation Back-up Phasor Data Storage (BPDS) Backup Phasor Data Storage (BPDS): Collects and stores the PMU data frame as is, for a limited time period. After that period, old data will be overwritten by new data The BPDS should have its own backup communication link, not shared with the main communication link The stored data may be polled by the ONS CDC in case of failure of the main communication link Data sent from BPDS will be unicast with CDC as it destination address 25
Substation Level Architecture (2) Substation Phasor Data Concentrator (SPDC): SPDC is optional and may be used to reduce the bandwidth requirement If used, the PMU data stream from the SPDC should also use multicast IP addressing SPDC and BPDS functions could be provided integrated in one device 26
27 Agent Control Center Architecture
Agent Control Center Architecture General Description When a PMU data stream reaches the Agents Control Center network, it will be routed directly to ONS CDC through communication links between Agents CC and ONS Control Center network If Agent installed his own APDC, the multicasting data stream will also be routed to it Agent Phasor Data Concentrator (APDC): Use of APDC is optional, allowing PMU data to be used by the agent The APDC gets data from the multicast PMU or SPDC data streams APDC may send phasor data to Agent s own SCADA or EMS servers 28
29 Central PDC Architecture
Central PDC Architecture Two level PDC structure with multiple front-end PDCs and a Master PDC Front-end Phasor Data Concentrators (FEPDC): Used to align received PMU data streams according to the time tag information and perform data scaling and other processing Should have sufficient large data buffer to keep the received PMU data for a specified period of time Should initiate the process to recover the lost PMU data when main communication link fails, send a request to the corresponding BPDS Data received from BPDS should be aligned with other PMU data already in the buffer 30
Central PDC Architecture (2) Master Phasor Data Concentrator (MPDC): Used to align PMU data stream from all FEPDC and send the aligned data to real-time applications server (SCADA-EMS) Databases: PMU data on-line database PMU Information and event trigger setting management database 31
Main Advantages of PMS Architecture Use of multicast technology conserve bandwidth and minimize system latency Optional use of Agent Phasor Data Concentrators (APDC) provide maximum flexibility both to ONS and Agents and allow to reduce system latency Use of multiple Front-End Phasor Data Concentrator (FEPDC) make the system highly scalable Use of Substation Backup Phasor Data Storage (BPDS) increase data reliability without impact on real-time applications 32
PMS Challenges System size Limited availability of PDC products Lack of PMU dynamic performance specification and tests Availability and cost of communication links 33
Thank You! Synchronized Measuring in Rio Praia Vermelha 2005 34
Phasor Measuring System Real Time Application Project 11.11 (ESTAL) 35
Historic Studies and research projects indicated the advantages of using PMU measurements in Real Time Tools In 2005, ONS approved the addition of the Project 11.11- Application of PMU Technology to Support Systems in Real Time Decision Making, in the company Action Plan ONS is in process to contract technical consultancy to support this project Project 11.11 will be sponsored by Energy Sector Technical Assistance Project - ESTAL Project of The Brazilian Ministry of Mines and Energy ESTAL funding: 60% from the International Bank for the Reconstruction and Development - IRBD (WORLD BANK) and 40% from the Federative Republic of Brazil 36
Scope and Status of Project 11.11 Main goal: To improve the State Estimation of the National Interconnected System NIS main grid The main grid considers: Four regions (north, northeast, southeast/mid-west and south) 230 kv, 345 kv, 440 kv, 500 kv, 525 kv and 765 kv voltage levels 351 substations and power plants Work statement: 8 activities - 13 products (reports and software developments) Estimated duration: 24 month Status: 5 companies answered The Expression of Interest of MME Proposal deadline: 20, June 2006 37
ONS Control Centers CNOS COSR-SE COSR-S COSR-N COSR-NE Supervisory and Control Systems The National Control Center is located in Brasília and uses an EMS (SAGE) developed by CEPEL (Brazilian Research Institute) The Southeast Regional Control Center is located in Rio de Janeiro. Its EMS is called SOL and was developed by FURNAS (Brazilian Transmission Agent) South, North and Northeast Regional Control Centers are located in Florianópolis, Brasilia and Recife, respectively. Their EMS are EMP Systems developed by AREVA (ALSTOM) COSR-NE COSR-N CNOS COSR-SE COSR-Sul
ONS Control Centers Applications COSR-NCO -Estimated Network: 267 buses -Modeled Network: 267 buses -Functions in use: SCADA, AGC, CF, EE -Functions installed: CA, VVD, DTS, EM (CA, PF, VVD, OPF) COSR-SE -Estimated Network: 111 buses -Modeled Network: 750 buses -Functions is use: SCADA, AGC, CF, EE -Functions installed: CA, EM (PF, CA, NEQ, CFP) CNOS -Estimated Network:1,480 buses -Modeled Network: 2,044 buses -Functions in use: SCADA, MONRES, ALIMTE, CF, EE, CA, OTS -Functions installed: EM (PF, CA, NEQ, CFP, OPF, SC) -Functions to install: DSA, VSA COSR-S -Estimated Network: 500 buses -Modeled Network: 500 buses -Functions in use: SCADA, AGC, CF, EE, CA -Functions installed: SA, VVD, DTS, EM (CA, PF, VVD, OPF) COSR-NE -Estimated Network: 400 buses -Modeled Network: 532 buses -Functions in use: SCADA, AGC, EE -Functions installed: CF, CA, VVD, DTS, EM (CA, PF, VVD, OPF) 39
11.11 Activities and Products 1. Economic Gains Using Phasor Measurement Report Identify the economic gains of Phasor Measurement System used in Real Time applications Report Establishing metrics to evaluate the cost/benefit relation of PMS adoption in RT operation 2. Complimentary System Specification Activities Report - Evaluation of the additional accuracy requirements regarding PMS used in State Estimation and RT applications 3. Survey of Phasor Measurement Units already installed in the NIS Report - Installations with available phasor measurement devices. Report Evaluation of additional needs required to permits the use of PMU already installed
11.11 Activities and Products 4. Studies for Optimal PMU Placement for State Estimation Report To define the minimum number of PMU considering State Estimation and RT applications Report To define the additional communication links required Activities 5. Evaluation of prospective PMS evolution Report To identify future PMS uses and the resources needed in each evolutionary phase 6. Software development to include phasors measurements in actual State Estimators Report - State Estimators and SCADA adjustments required to use PMU data Report - Proposal for the evolution of ONS state estimator architecture
11.11 Activities and Products 7. Applications for Real Time operation Report To specify software to be used in decisionmaking activities of real time operation Activities 8. Development of new real time applications Development and/or customization of additional support software to be used in real time decisionmaking activities.
Thank You! Bad Synchronized Measuring in Niterói Praia de Icaraí yesterday 43
Synchrophasor Applications on Brazilian Interconnected System International Conference on Phasor Measurements Applications June, 2006 Rui Menezes de Moraes Héctor Andrés Rodriguez Volskis