Advanced Protection and Control Technologies for T&D Grid Modernization i-pcgrid Workshop San Francisco, CA March 31, 2016 Jeff Shiles, Principal Manager Protection & Automation Engineering Southern California Edison Dr. Farid Katiraei, Director Emerging Technologies & Microgrids Quanta Technology
Presentation Overview Grid Reshaping Phenomena Traditional SCE Practices in Protection & Controls Methods and Schemes for Advanced Protection, Control, and Automation SCE Grid Modernization Highlights SCE Protection & Automation Engineering Roadmap 2
Grid Reshaping Phenomena Renewable Generation Energy Storage Microgrids DSOs High penetration issues (PQ, stability and protection) Smart inverter controls Fault Current Charging load Integration Control functions Performance evaluation and maintenance Design & Protection Safety Control & Operation Application evaluations Communications infrastructure Market Participation Grid BESS Load Wind Generation PV Generation BESS PV Generation Generator 3
Utility Integration Challenges Challenges for the next generation power system: Microgrids & Distribution System Operation Regulatory Challenges: Ownership of generation Administrative burden of regulation Technical Challenges: Bi-directional power flows Fault current contribution Unit Level Volt/VAR support Islanded Operation Economic Challenges: DG technologies still costly and with uncertain lifetimes Business model still undeveloped 4
Traditional SCE Practices in Protection & Controls Distribution Circuit Protection Non-directional phase & ground overcurrent at substation CB Automatic reclosers on many circuits Extend reach of overcurrent schemes Sectionalize circuits to enhance reliability Subtransmission Line Protection Line differential (primary) Large fleet of electromechanical relays (e.g., HCB) Both copper and fiber communication channels used Phase & ground overcurrent (backup) Non-directional at source terminals Directional at network (i.e., non-source or receiving) terminals 5
Traditional SCE Practices in Protection & Controls Switch-and-a-half scheme for feeder automation fault Step Time (sec) Operation 1 00 Fault occurs, Feeder 1 CB trips 2 15 Feeder 1 CB recloses (test) 3 15 Feeder 1 CB trips (fault persists, test no good) 4 30 Feeder 1 RCS opens automatically 5 55 Feeder 1 CB recloses (test good, ½ circuit picked up) 6
Example Case: Impact of DER on Automation fault DG Miscoordination due to change in fault current level Delaying auto-reclosing scheme Blinding RCS from automatic disconnection 7
Traditional SCE Practices in Protection & Controls Substation Automation (SA-2) for automatic load restoration, remote & local switching, and enhanced monitoring for Grid Operations Function Description Reclosing Metering Relay Protection Hardware Failures Switching Alarms Reclosing is provided by the PLC and UR relays. The PLC provides coordinated reclosing between multiple devices. The UR relay provides reclosing for single devices. Metering information is continuously updated by SA-2 relays to the local Human Machine Interface (HMI) and remotely to EMS. SA-2 incorporates traditional relay protection as well as enhanced protection provided by Permissive Trip Bus (PTB) and Fast Bus Blocking (FBB). The SA-2 system continually monitors hardware in the substation. If any piece of hardware fails within the SA-2 system or substation, an alarm is initiated locally and remotely. Circuit breakers, reclosers, relay protection, battery charger functions and LTC/regulator tap position can be controlled remotely via the EMS or locally via either the HMI or the relay associated with the position. Substation alarms can be acknowledged remotely by EMS or locally at the HMI or the relay front panel. 8
Traditional SCE Practices in Protection & Controls 9
Advanced Protection, Control, and Automation Feeder automation and self healing Advanced protection schemes Enhanced Monitoring and visibility Remote control switches and automation algorithm to apply topology changes Adaptive protection & communication based protection: peer to peer High resolution, time synchronized monitoring (with PMUs) Reliability and resiliency Intentional islanding and Microgrid 10
Loop Schemes and Automatic Restoration Close Open Major loads centers are divided and protected by interrupters and relays, in a closed loop topology and/or with tie-switches to adjacent circuits Communications among relays in the substation and relays in the field Relays to communicate via GOOSE messaging Relays send permissive trip and block signals depending on the direction of fault current 11
Localized, Peer-To-Peer Protection Approach Intelligence resides in local protection devices located out on the feeders Local protective devices make switching decisions based on local measurements and information acquired from peers Also have localized automation in the form of standalone IED Control Center Protection & DA logic in the field Feeder Locations Drawn by R. Uluski, EnerNex Corp Substation Master Substation A feature of this approach is that it doesn t absolutely require a distribution SCADA system 12
Microgrid Protection Advanced Solutions Grid-connected mode: Revise existing protective settings based on new fault levels (contribution of DERs) Islanded mode: Switching between protection setting groups based on the status of the POI CB New protection settings Using voltage-restrained OC relays Communication assisted protection: Load Load PV2 PV2 Load Load PV1 Backup Transfer Trip PV1 Backup Transfer Trip F1 Backup Transfer Trip I I RCS1 I I F2 Load Cap. Load Cap. Cap. 13
SCE Grid Modernization Requirements The future grid will require investments in technology that build capabilities enabled by the future workforce and process improvements. Advanced capabilities needed to support higher penetrations of DERs Monitor Predict Control Grid Assets Investments needed to achieve desired capabilities Communications and Interoperability Technology Solutions Assets installed on the grid need to provide additional intelligence to SCE planners, engineers, and operators to better measure and manage the grid Data (both SCE and third party owned) needs to be collected and communicated to back office systems in near real time for proactive control actions Technologies deployed at SCE need to be revamped to accommodate and act on the additional intelligence being obtained from grid assets People Strategy Increased resource requirements Evolving skill sets Training needs Enabled By: Business Processes Work management Design standards Procurement & planning integration 14
SCE Grid Modernization Vision 1 3 1 2 1 2 Future state based on evolving energy landscape 1 1 2 More automated and flexible, with more sophisticated voltage control and protection schemes Facilitates increasing renewables & twoway power flow 1 2 3 Cyber mitigation must be included 15
SCE Protection & Automation Engineering Roadmap 2016 2017 2018 2019 2020 Distribution Remote Intelligent Switch Protection & Control Inverter-Based Microgrid Protection Smart Inverter Models & Interconnection Req ts Microgrid Pilot (DRP Demo E ) Adaptive Protection Settings Feeder Modeling & Simulation Enhancements High Impedance Fault Detection Devices / Schemes / Standards Standardized BESS Protection Packages Centralized Settings Management Substation Substation Automation (SA-3) B-Station Design Standards SA-3 A-Station Pilot (Viejo Substation) B-Station Process Bus Pilot SA-3 A-Station Design Standards Subtransmission Line Terminal Relay Replacements Subtransmission System Model Updates & Protection Coordination Reviews Advanced Relay Standards 16
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Expected Result People and Process Technology GRC Cycle SCE Grid Modernization Road Map SCE developed a plan to implement a phased approach. Transformation is expected to take place over multiple General Rate Case cycles 2015-2017 2018-2020 2021 2023 + Implement foundational Information Technology, communication systems, and system planning tools Enhance automation and improve interoperability with Distributed Energy Resources Optimize operation of Distributed Energy Resources and distribution market operation Align work management and develop workforce strategy Ramp up resources and develop talent pipeline Compliance, safety, and reliability Preparation for future grid state New business opportunities enabled Full deployment of grid modernization New distribution system platform for distribution market operations 19
IT T&D SCE Grid Modernization Roadmap Short Term 2015 2016 2017 Substation Automation (SA3) Programmable Capacitor Control Grid Assets Remote Fault Indicators Modern Microprocessor Relays (Subtransmission) Energy Storage Distribution Volt VAR Control Retrofit existing Remote Controlled Switch with Enhanced Telemetry Remote Intelligent Switches Retrofit existing Remote Auto Recloser with Enhanced Telemetry Communication Field Area Network Fiber installation & IP Upgrade Technology solutions Foundational Long Term Planning Tool Set Generation Interconnection Application Tool DRP External Reporting (DERiM) Distribution Circuit Modeling Grid and DER Management Grid Analytics Applications System and Information Architecture Geospatial Information Systems Connectivity Models Grid Analytics Platform Data Integration Cyber Security 20
Foundational Tech. Solutions Comm. Grid Assets Operational Benefits of Grid Modernization Investments Benefits Description Substation Automation (SA-3) Volt/VAR Optimization Distribution System Protection Fiber Installation Field Area Network SA-3 s open standards-based platform helps avoid vendor lock-in, and reduces the time and resources necessary to design, deploy and maintain substations. Volt/VAR optimization promotes conservation voltage reduction, which reduces customer energy use by 1%-4% without requiring changes in customer behavior. Advanced system protection capabilities (such as fault location, isolation and restoration techniques) can reduce the number and duration of outages, which improves reliability and customer satisfaction, and decreases O&M costs (less windshield time and equipment wear-and-tear). Enables low latency, high bandwidth, secure interconnection of substations and device data exchange allowing the distribution network to adapt as the grid changes to DER adoption. Enables wireless, secure, last mile communication to support both hierarchical and distributed control of field devices and DER s Long Term Planning Tool Set Gen. Interconnection App. Tools DRP External Portal Distribution Circuit Modeling Grid & DER Mgmt. Systems Grid Analytics Applications System/Information Architecture Connectivity Models (GIS-based) Grid Analytics Platform Data Integration Next-generation planning tool that requires SCE to identify available capacity for each distribution circuit and to leverage DERs as grid assets to meet future load growth. This results in improved asset utilization, deferred capital investments and reduced O&M. Automating the intake process for customer Net Energy Metering applications would reduce processing costs and improve customer satisfaction Provides more detailed system interconnection maps via web-based tool for generation project developers. This should relieve CPUC scrutiny on this issue while improving the satisfaction of the developer community. Improved ability to model distribution circuits (with high penetration of DER) for interconnection review, voltage studies, and power flow analysis. Enables system operators to operate an electric grid with high penetration of DER. These tools provide greater situational awareness (current and forecasted) and control capabilities of SCE-and 3 rd party-owned DER, which is critical for maintaining the safety and reliability of the electric system. Improved Transformer Load Management and phase accuracy would improve state estimation (transformer and circuit loading) and outage notification accuracy. Leveraging Smart meter data for load analytics provides better situational awareness in operations and switching. Enables alignment and integration of the various grid modernization processes and technologies. Provides single system of record for end-to-end modeling capabilities and maximizes value of all systems dependent upon the connectivity model Big-Data Analytics platform to collect, process and analyze data from meters and devices to determine the impact of DER on the grid Improves data quality and consistency of electrical system data (e.g., connectivity, device status). This is a prerequisite for developing grid modernization tools and processes for planning, monitoring and operating the grid. 21