Development of Monitoring, Protection, and Control Technologies & Impact on Modern Electric Networks. Vahid Madani

Transcription

1 1 Development of Monitoring, Protection, and Control Technologies & Impact on Modern Electric Networks Vahid Madani

2 Pacific Gas and Electric Company Incorporated in California in 1905 One of the largest combination natural gas and electric utilities in the United States. Based in San Francisco Diverse service territory Natural gas and electric service in northern and central California 935 electric substations 46,260 miles (76,300 kilometers) of natural gas transmission and distribution pipelines Approximately 22,000 employees Regulated by the California Public Utilities Commission San Francisco Los Angeles Bakersfield

3 Pacific AC Intertie (PACI) British Columbia Alberta Washington Montana Major Intertie Corridors In WECC (Western Electricity Coordinating Council) Serves 72 Million Population Oregon Idaho Wyoming Nevada Utah Arizona Colorado New Mexico PDCI DC Link, 1000kV PACI AC Corridor, 500kV PACI AC NE / SE, 345kV

4 159,000 Circuit Miles 60kV 500kV Transmission and 4kV-21kV Distribution Number of Substations Total 935 Transmission 167 Distribution 768 Generation Mix Estimates: Hydro 4,000 MW Irrigation 1,000 MW Thermal 500 MW Geothermal 500 MW Renewable / QF 4,200 MW Nuclear 2,500 MW IPP 9,500 MW Total 22,200 MW

5 PG&E Energy Delivery Transmission Voltage (Circuit Miles/ Kilometers) 500 kv 1,330 / 2, KV 5,270 / 8,785 Service Area: 70,000 SQ miles / 115,000 SQ kilometers in Northern & Central California West - Pacific Ocean; East Sierra Nevada North Oregon & Eureka; South Bakersfield Population served - 16 million 115 KV 6,040 / 10, KV 5,525 / 9,210 Total 18,165 / 30,285 Peak Demand PG&E: 30 GW California Control Area: 58 GW 5

6 Outline Introduction Challenges Operations Technologies Applications Requirements Balancing technology and Reliability Standards and Conformance Cyber Security IT requirements to support OT functions Business Direction and Roadmaps 6 6

7 Grid Challenges Aging infrastructure Generation location relative to major load centers Transmission expansion to meet growing demands Congestion management Distributed resources Dynamic reactive compensation Grid ownership vs. system operation (or between Countries) Reliability coordination Supply and cost of natural resources for generation Need for oversight or Regulatory Audits Balancing between resource adequacy, reliability, economics, environmental constraints, and other public purpose objectives to optimize transmission and distribution resources to meet the needs of the end users. 7 7

8 Complex Systems Coordinated functions 8 Aging Infrastructures Neighboring Control Area Status Load Centers Status End User Demands (e.g: Reliability Availability) Economics & Market Fluctuations Reactive Compensation Control Systems Status Interconnected Power System) Regulations Environmental Generation Status Frequency Deviation Voltage Variations Phase Angle Measurements System Studies, Modeling, Analysis under System Stress Fuel and Natural Resources Data & Findings Applied for New Strategies Distributed Resources PMUs Wide-Area Monitoring IEC New Standards EMS / AGC Enterprise Systems Affiliates Governing Bodies Contingency Analysis

9 Increased Frequency of Major Blackouts Global Power Outages & Findings Influencing Grid Modernization Strategies & Planning

10 Global Power Outages Highlights Common Threads Italy, 2003: 57M people o Heavy import to Italy NE-US Can, M people o 2 hours before disturbance 500kV line disconnect o Heavy power flow in region o Brazil & Paraguay, 2009, 87 Million People o Three key transformers short circuited in Brazil o Crucial high voltage lines disconnected - Instantaneous loss of 14 GW of power, climbing to 28GW S. California, Arizona, México, 2011, US, M people o Heavy import to San Diego o 500kV line trips o Generation tripped in Mexico o Heavy N-S flow on Path 44 India, Million - Largest outage ever o Heavy power transfers due to weak interregional corridors due to planned and forced outages o High Loading on 400 kv link, due to unscheduled interchange, not corrected o One 380 kv line sags into a tree and disconnects o Heavy load through parallel line that sags into tree and tripe o 220kV/110 kv trip on overload, isolating Italy o One 500 kv line sags into a tree and disconnects o Heavy load kv lines o kv lines disconnect due to overload o 345 kv lines trip on overload o Power loss causing a Secondary incident, shutting down power generation at Itaipu (largest hydroelectric dam in operation) shared with Paraguay o Two transformer units & two 161kV lines trip on overload o More 161 kv lines and units (Mexico) trip (loss of 420 MW) o Path 44 trips on overload o 400kV line trip on zone 3 relay disconnecting North from South o Heavy load on transmission lines causing cascading failures o Voltage declines and power units trip o Power oscillations and voltage decline cause cascading separations Blackout occurred in 2.5 minutes System restored in ~5 hours o Voltage declines and power units trip o Power oscillations and voltage decline cause cascading separations Blackout occurred in 3 minutes System restored in ~1-2 days o Voltage declines, causing cascading separations power loss Blackout occurred in minutes System restored in ~3.5 to 6 hours o Voltage declines, power units trip San Onofre and others o Power oscillations & voltage decline cause cascading of 230 kv lines Blackout occurred in 11 minutes System restored in ~1 day o Voltage declines causing trip of all major power stations o Power oscillations and voltage decline cause further cascading separations Blackout occurred in 3 minutes 80% of System restored in 15 hours

11 Recommendations After 2003 U.S. & 2006 European Outages August 14, 2003 Outage: U.S.-Canada Power System Outage Task Force Report "A valuable lesson is the importance of having time-synchronized system data recorders. The Task Force s investigators labored over thousands of data items to determine the sequence of events, much like putting together small pieces of a very large puzzle. That process would have been significantly faster and easier if there had been wider use of synchronized data recording devices " Recommendation 12a The reliability regions, coordinated through the NERC planning committee, shall within one year define regional criteria for application of synchronized recording devices in power plants and substations November 4, 2006 Disturbance - UCTE Final Report System UCTE-wide Awareness System " On November 4, this was true more than ever the information about the split of the system into three areas was available to some operators with significant delay. This issue might be solved via a dedicated central server collecting the real-time data and making them available to all UCTE TSOs. In this way, each TSO will obtain within a few minutes essential information about disturbances beyond their own control area. " Recommendation 4 - UCTE has to set up an information platform allowing TSOs to observe in real time the actual state of the whole UCTE system in order to quickly react during large disturbances.

12 Integrating Lessons Learned FERC Report, Situational Awareness Angular Separation Ability to determine, in real time, the standing angles that would result following major transmission line outages Placing PMUs in locations such that standing angles can be seen directly by system operators in SCADA/EMS systems Real-Time External Visibility Lack of adequate awareness of external contingencies that could impact one s system Real-Time Tools E.g., Without having tools in place to determine the phase angle difference between the two terminals of a line after the line tripped, one should not / cannot commit to restore the line quickly. Need seasonal and next-day contingency analyses that address the angular differences across opened system elements Having, but not using the real-time tools to monitor system conditions Real-Time Contingency Analysis (RTCA) tools need to be functional and operating

13 Need for New Approaches Planning, recovery, and operating practice issues need to be addressed in the context of event recordings, relay settings, distributed data sources, and social/environmental impacts. The electric grid is severely constrained by its highly heterogeneous and distributed nature, both spatially and portfolio of information systems employed Need for Enterprise solutions Reduction of costs for maintenance and upgrades Asset Management: System functionality, data sources, legacy Managing regulatory compliance Minimizing risk when implementing new systems; Standardized protocols and near real-time metadata exchange Ease of implementation and deployment Competitive business practices 13 13

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15 Process The need for long-term Operation Technology (OT) & Information Technology (IT) roadmaps Need converging roadmaps to achieve OT/IT convergence Operations Applications requirements Managed IT infrastructure to handle: Priority Latency Reliability / availability / redundancy Modularity / expandability Continuous system monitoring Conformance and interoperability Sustenance and Sustainability System Improvements & Enhancements Integrating lessons learned Service level agreements at enterprise OIS Interface Load Trending Voltage & Var. Control Analog, Status & Alarms Auto & Remote Switching Emergency Analysis Capacity Analysis Load Trending Fault Locating Equipment Alarms Work Mgmt. Interface Equipment Diagnostics System Operation Analysis Reliability Analysis Equipment Rating 15 15

16 16 Strategies and Applications.. Wide-area monitoring, protection, & control systems o Synchronized Measurements o Wide-area visualization techniques o Advanced feedback control schemes Investments in standardized infrastructure system upgrade Disaster Recovery Architecture and Security Environment Accurate and user-friendly tools for system planning, operation, and protection studies Information semantics to improve grid resiliancy under complicated power system conditions 16

17 Leveraging Technology and Collaboration In Shaping the 21st Century Grid A Perspective on Synchrophasor Applications

18 Experiences with SIPS Global Participants IEEE PSRC Report % 9% 15% 3% 6% 3%

19 19 WECC Pacific AC Intertie and Northeast Southeast (NE-SE) Separation Scheme British Columbia Washington Alberta Montana NE SE Separation: Islands are formed by controlled separation of transmission at Tie Locations between power companies Oregon Idaho Wyoming Nevada Utah Colorado Arizona New Mexico

20 Major SIPS Western North America Neighboring Systems Neighboring Systems Neighboring Systems Pacific NW Remedials Load Break Insertions AGC Generation Reactive Support Load Groups Olinda Gen Groups SIPS System Integrity Protection Scheme RAS Remedial Action Scheme Cascade Table Mt. Hyatt Round Mt. Caribou/ ButtValley Maxwell Sierra Delta Pacific Power Dos Amigos Tracy San Luis Helms Midway Wheeler Ridge Wind Gap Buena Vista Edmonston Pearblossom Neighboring Systems RAS monitors status of Circuit Breakers and Undercurrent Relays needed to determine equipment status. Decisions made in less then 2 Cycles Overall Throughput < 10 cycles Remedial Actions are predetermined by information stored in RAS Tables

21 Frequency (Hz) Automatic Preventive Measures (Under-frequency load shedding and SPS examples) System Frequency In Northern California August 10, 1996 Beginning At 15:46:41 PST FREQ Time (Seconds) Automatic Power Systems Protection Schemes (PSPS) saved the day, and limited outages to 7.5M people on one of the hottest days of the year Note: Western Region serves more than 72 million people

22 Synchrophasor Roadmap 2012 (26 Apps.) 22

23 Uncoordinated Coordinated Power Systems Functions Critical Timing - Reaction time Short-circuit faults, Fast dynamic response Protection FACTS Fast, direct local action Fast system contingencies: Voltage & angular instability Cascading Wide Area Measurement, Protection, and Control (WAMPAC) Dynamic wide area view Fast coordinated action System operation Long term stability Market transactions SCADA /EMS Steady state view Slow action Area for information semantics in system protection benefits of machines closely interacting at human conceptual levels Dynamic real time Steady state s 23

24 24 Top Level Business Plan Synchrophasor production level system is to provide wide-area data collection and management enabling smart grid functionality Regulatory Requirements Regulatory approvals (i.e: DHS, DOE, NERC, FERC, UCTE,.) NERC standards to be accommodated PRC-002 Regional Disturbance Monitoring and Reporting Requirements CIP (Critical Infrastructure Protection) standards Working with Partners and Stakeholders Industry collaboration and planning Maintenance practices and training Develop Strategy w/ Stakeholders Engineering & Proof of Concepts (Trial Field Implementation) Procurement & Implementation DHS & DOE Departments of Home Land Security & Energy NERC North American Reliability Corporation FERC Federal Energy Regulatory Commission UCTE - Union for the Co-ordination of Transmission of Electricity

25 Synchrophasor Applications (in Random order) Integration of PMU data into EMS Integrated EMS & RAS schemes Substation State Estimation Accurate Fault Location Model validations Generator modeling Event Analysis Situational Awareness Applications including Wind issues Studies and Advanced Warning Systems Predictive stability/ instability indicators and immediate out-of-step indicators Reactive power reserves - optimization Trending and Grid Dynamics Tracking Phase angle baselining Wind penetration impact studies Adaptive Protection And Control HVDC-light ramping (and/or modulation) On-line DSA (Dynamic Stability Analysis), integrated into PMU, used for RAS. Response--Based Reactive Switching Adaptive Islanding, Load Shedding and Restoration Power System Oscillation Damping [Controls (continuous)] Wind Site Voltage Control

26 Synchrophasor Project Background Deployment of a large scale Synchrophasor measurement system to improve PG&E/WECC grid reliability Open, Flexible, Interoperable, Secure, and Expandable Proof of Concept (POC) facility has been invaluable: Risk Management No time for Redoing or will figure it out later Help prevent delays at time of field installation Identifying and remedying some product and system integration issues with potential for serious delays during commissioning Addressing international standards Install PMUs and PDCs that communicate IEC standard and 120 phasors More sustainable over life cycle CIP compliance WECC Western Electricity Coordinating Council

27 Applications and Functions 1. Situational Awareness, Visualization and Alarming for Electric Transmission Operators Unbalance power applications Abnormal angles Abnormal voltages Line overloads, Dynamics oscillations (small signal oscillation) monitoring and System restoration 2. Enhanced Energy Management Systems and State Estimation (EMS) Adding synchrophasor measurements to existing SE measurements Track dynamic state changes of a system during disturbances EMS measurement support Volt-VAR Optimization 3. Post-Disturbance Event Analysis for Planners and Engineers Substation level data analysis System level event analysis 4. Operator and Engineering Training - Enhanced Dispatch Training Simulator (DTS) 5. Cognitive Tasks and Human Performance Analysis 6. Provide interfaces with EMS and with third parties 7. Distributed and / or Linear State Estimation Copyright: Property of Pacific Gas and Electric Co. P 27 27

28 Purposes of POC Architecture and Proof of Concept (POC) Test and resolve dataflow interfaces from Substation to Control Center Test failover of the integrated system to identify gaps and design EMS Applications with Synchrophasor Measurements Identify User Interface configuration issues Take results into the delivery configuration where applicable Verify the results of Cognitive Task Analysis for visualization and operator interface Data Information Knowledge Meaning World Wide Web Semantic Web

29 Benchmarking Exercise Deployment Strategy Applications Aggressive Big bang all real-time closed loop control, protection, operation & other applications Control room functions; some real-time applications Data visualization and operation analysis in control room E C A B Monitoring; visualization & operation analysis outside of control room I F H D G Conservative Number of PMUs X PMU Technology Deployment, On-going US Synchrophasor Projects 29

30 Visualization and Control -- Challenges and Needs for an Evolving Industry Structure Source: US Department of Energy CURRENT AND PROPOSED LEVELS: Wide-Area Level 3 DOE Situation Awareness MONITORING AND CONTROL: Situation Awareness for Emergency Response Wide Area Level 2 FERC Reliability Standards Performance Standards Performance, Monitoring, Notification and Reporting Wide-Area Level 1 Level 3 Level 2 NERC Emerging Wide-Area Reliability Performance Monitoring and Compliance ENERGY MANAGEMENT SYSTEMS (EMS) RTO, ISO, CONTROL AREA SCADA - REGIONAL CONTROL CENTER Real Time Wide-Area Monitoring and Compliance for Interconnections Load-Generation, Inter-Area Schedules, And Transmission Adequacy System State Estimation, Security Analysis, and Security Constraint Dispatch Regional Load-Generation and Grid Switching Control Level 1 LOCAL CONTROL SUBSTATIONS LOCAL CONTROL GENERATION PLANTS Local Generation and Substation Control 30

31 31 Operations Technology Applications - 1 EMS and SCADA State Estimation Model-based stability analysis and monitoring E.g., Online Dynamic Stability Assessment Remote switching (human-in-the-loop) Requirements Modest data volume and latency (in seconds) Lower latency for switching applications 31

32 32 Operations Technology Applications - 2 EMS and Synchrophasors Enhanced State Estimation Getting closer to State Measurement Linear and / or Distributed Situational Awareness and Alarming Angle monitoring Voltage stability Contingency Analysis and Reactive Margin Knowledge Oscillation monitoring Fault Location Requirements >100X higher data volume compared to SCADA Mid to Lower latency (several 100 s of ms end-to-end) Moderate reliability 32

33 Strategic Team: Academic & Testing Applications PG&E, ALSTOM, GE, Mississippi State University, Quanta GeorgiaTech, OMICRON / RTDS / Virginia Tech., Washington State Univ. SynchroPhasor Applications for the Control Center Multi-host Redundancy (ISD Link)

34 Megawatts Tehachapi Wind Generation in April 2005 Could you predict the energy production for this wind park either day-ahead or 5 hours in advance? Each Day is a different color. Day Day Day 5 Day Average Hour

35 35 Operations Technology Applications - 3 System Planning Data archiving and use of field information Event Analysis Use of various data sources (preferably synchronized) Requirements Large data volume but not real-time data Long-term high-resolution data archiving 35

36 Hierarchy Structure for PMU Placement Decision Criteria GOAL DECISION CRITERIA ALTERNATIVES 36

37 Volt-Angle The ability to visualize voltage - angles as the power flows through the electrical system 1. Relative Voltage Angles with respect to common Reference The difference between the measured voltage angle by a PMU location, and the voltage angle measured at a common reference bus 2. Voltage Angle Differences between a pair of nodes in system The Voltage Angle Difference is computed as difference in the voltage angle between two locations: typically between the source and sink areas of the system, or across a known corridor or interface Note: The two locations don t necessarily have to be at the two ends of a transmission line. 3. Voltage Angle Rate-of-Change to detect sudden disturbances in the system Computed as change in voltage angle over a userdefined time period (e.g. 1 second). Represents relatively fast changing angles in time (e.g. pre- and post-event angle change during a disturbance) Copyright: Property of Pacific Gas and Electric Co. P 37 Relative Angle Voltage Angle Differences Voltage-Angle Rate of Change

38 38 Operations Technology Applications - 4 Asset Management Online asset condition monitoring Use of relaying data and archiving Data form Modular Protection / Automation / Control buildings (substations) Combining data from various sources Relays and sensors Nameplates Infrastructure and standards (IEC 61850)

39 39 Operations Technology Applications - 5 Automated Control Applications Requirements Moderate data volume Very Low latency (several 10 s of ms end-to-end) Very high reliability Combined Transmission and Distribution OT needs Need flexibility and options within the IT infrastructure

40 Example Post Event Analysis Tools

41 41 Time of Event (22:55 22:59 UTC) 2000MW Gen drop Celilo-Sylmar DC Intertie DC Intertie restarted Series and Shunt Capacitors inserted

42 42 Time of Event (23:00 23:12 UTC) Series Capacitors bypassed Shunt Capacitors removed

43 43 Use of Standards Leverage National and International Standards Helps deploy commonly available and supported solutions Eases partnership with solution providers Uses economy-of-scale beyond a project size Simplifies specifications and communication Standards can support solution longevity Usually provide transition path as technologies approach obsolescence Helps simplify interoperability Conformance and Proof-of-Concept testing for compliance with standards helps interoperability

44 GPS Phasor Measurement Systems Timing standards IEEE 1588 or C Communication standards IEEE C IEC ICCP Phasor Data Concentrator Real Time Monitoring & Alarming 44 Measurement standards C IEC * Substation PDC PDC Guide Requirements, System Communications, Testing IEEE C PDC Standard IEEE C Future real-time controls Installation, calibration, test guide C Other utility PDC Data Storage Off-line Dynamics Analysis Data storage standards IEEE C COMTRADE * Not yet released

45 Operational Efficiency Sample Metric Details Metric Description Base Target Operational Metrics Cost / Scheme Installed Cost / Building Installed Cycle-Time / Terminal Completed Cycle-Time / Building Completed Program Budget Variance Project Budget Variance Project Cycle-Time A shared operational metric between projects and the program. Measure for a project of the average price per installed scheme in dollars ($). Measure for the program of the average price per installed protection scheme in dollars ($). A shared operational metric between projects and the program. Measure for a project of the average price per installed building in dollars ($). Measure for the program of the average price per installed building in dollars ($). A shared operational metric between projects and the program. Measure of the average cycle-time per terminal installed. A shared operational metric between projects and the program. Measure of the average cycle-time per building completed. Measure representing the dollar ($) difference between the allocated program budget and the program expenditures for the fiscal year. Measure representing the dollar ($) difference between the estimated project budget and the actual project expenditures. Total cycle-time, in days, for project completion. 51

46 Business Decision 52 The OT and IT convergence will significantly affect how a utility operates, accordingly, it is a decision which should be based on the utility s business direction and strategy Data management and responsibility! Operational Decision Making and Regulatory Arena For successful convergence, change management for the business processes has to be addressed Significant shift and needing additional skillsets - Growing pain for the enterprise

47 Synchrophasor Situational Awareness Tools Copyright: Property of Pacific Gas and Electric

48 Situational Awareness Tools "...by marrying synchrophasor "measurement-based" analytics with "model-based" stability analytics, we're building the next generation Energy Management System capable of assessing power system dynamics and grid stability in real time for improved reliability and better asset utilization.

49 Summary Business process and decision Generation Mix and Grid Challenges Ways to maximize benefits from a complex system Roadmap alignment between OT and IT Competing OT Applications Requirements Cyber Security Standards Information Technology requirements to support Operational functions Need for prioritization and benchmarking Organizational and skillset transition 55

50 56 END Thank You Questions?