Smart Grid Automation and Centralized FISR

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1 Smart Grid Automation and Centralized FISR March 21, 2016 Mike Colby Senior Engineer Distribution Control Center

2 Smart Grid Automation and Centralized FISR Remote Controlled Devices & Communication Distribution Management System (DMS) FISR usage Managing roll-out Future development 2

3 About PPL Electric Utilities Facilities: 4kV to 500kV Headquartered in Allentown, PA 1.4 million customers and load peaked at 7844 MW 400 distribution substations 29 counties in central PA, 6 cities including Harrisburg Deployed DMS in 2014 Completed FISR Deployment May

4 Smart Grid Rollout U.S. Department of Energy: Federal Stimulus Grant $19M Grant w/ $19M PPL Match Smart Grid Pilot: 160 Device Installations 50 Feeders in Harrisburg 60,000 Customers 2013 Phase I: 374 Device Installations 52 Feeders in the Poconos 45,000 Customers Distribution SCADA Phase 2: Core DMS Implemented ~4000 Device Installations ~1200 Feeders FISR implemented 4

5 Choice of Distribution (DA) Automation Devices Capacitors 3PH investigating single PH switching MOABS no longer installed ~1000 on the system Inspections & adjustments Reclosers 3 phase gang operated Less maintenance Reclosers Single phase operation Minimal cost added Opportunity for 1PH switching on selected feeders 5

6 DA Device Information & Control Recloser Configurations Recloser Sectionalizer Switch Reconfigurable Remotely Capacitors Open / Close Neutral Amps Indication MOABS Open / Close Volts Amps Fault Indication 6

7 Unsolicited / Requested Data 7

8 Device Placement Strategy Pilot locations: Harrisburg Poconos 2013 Placement All feeders, Mid-point & Tie 2016 Sectionalizing device every 500 customers 2019 Large customer point of contact 8

9 Distribution Automation Communication First Attempt - Contracted Web based 3 rd party hosted 2G cell radios Second Attempt - Wimax Company owned mesh type radio network Direct path radio communication Unreliable - Communication challenges Third Attempt 3G Cellular AT&T and Verizon 3G cell radios 1st RTUs Migrated to server based data 9 concentrator

10 Network Topology Overview 10

11 Future Communications Leverage AMI System AMI Mesh Communication Network Deployment December 2016 June 2019 Migrate DA devices to mesh network Benefits Cost Benefit Cellular cost Reliability Drawbacks o Latency 11

12 Automatic Device Control Two approaches to Automation De-centralized (Local Control) All of the automation is controlled in software packages located in substations. Typically very simple and quick to install, Disadvantage of being laborious to maintain long term. Centralized All automation information is brought into a centralized computer system (DMS), Advanced algorithms Analyze network topology and current system conditions, Determines the best switching solution. 12

13 Choice of DMS Vendor PPL Chose the Alstom (now GE Grid Solutions) DMS system Handles unbalanced power flow Synergy with PPL s TMS (already Alstom) History and Development 2012 Engaged with Vendor 2014 Power flow models complete 2015 Full Automation Pilot 2016 Full System Implementation (FISR) 13

14 DMS Analytical Functions DPF runs periodically, triggers by user and/or topology change Automatic Fault Location Protection Validation Fault Isolation and Service Restoration (FISR) Load Volt/VAR Management (LVM) Short Circuit Calculation in local study mode Advanced Feeder Reconfiguration Planned Outage Switching in local study mode FISR Contingency Analysis in local study mode 14

15 Centralized Device Control DMS Implementation: Layered on top of the existing SCADA Allowed operators to make all of the decisions and switching Model developed & advanced applications were fully vetted Key Benefits: No additional system programing required as feeder configurations change. Once a new controllable device is installed it is available to the software. Updates to software can be done on a global level one time. 15

16 Fault Recovery Timeline Manual Mode Alert Operator Restore Upstream Restore Downstream Fix Fault 5-10 minutes hr hr Auto Mode Localized Control Restore Upstream Alert Operator Restore Downstream minutes 5-10 minute hr Fix Fault Auto Mode Operator Control Alert Operator Restore Upstream Restore Downstream minutes minute 5-10 minute Fix Fault Auto Mode DMS Control Alert Operator Restore Upstream Restore Downstream 1-4 minutes minute Fix Fault 16

17 Restoration Improvement Q: How do we reduce the fix fault portion of an outage? A: Using technology - determine the location of the fault. Direct the crews more efficiently to the location of the fault. How?, with three pieces of information: Device fault indication Calculated location using impedance model utilizing fault current Customer Outage Calls Dependencies: Correct GIS Data 17 Accurate Impedance / Power Flow Models

18 Fault Isolation Service Restoration (FISR) FLISR fault location, isolation & service restoration FISR Puts the Smart in PPL s Smart Grid Utilizing Automated Devices with Alstom s DMS to: 1. Identification of Fault Location Significant reduction of crew s time patrolling line = faster restoration. 2. Isolate Faults, Restore Customers Fully Automated Switching Restore Service to as many customers as possible. 18

19 FISR Operation 1. Identifies fault location 2. Generates switching plans Isolate faulted sections Restore non-faulted sections. 3. Prioritizes switching plans & provides multiple solutions Operational objectives identified Minimize unserved load Minimize switching Constraints identified Voltage Create no load flow violations Protection settings validation 19

20 FISR Modes of Operation Advisory provide operators with switching solutions to switch manually Open Loop - ranks various switching plans, user to execute Closed Loop - ranks various switching plans, automatically executes FISR configured to identify the faulted section via receipt of Fault indication from remote operated devices Fault location based on impedance is an option not implemented FISR won t solve if a fault indication is not received. 20

21 FISR Sequence Fault occurs between MOAB #1 and #2, North Breaker Trips to Lock-out Locate the fault, MOAB #1 Indicates Fault and MOAB #2 Indicates No Fault Isolate fault, Open MOAB #1 and #2 Restore unfaulted feeder sections, Close Tie MOAB and Close North Breaker Fault Indicated FI No Fault Indicated FI FI North Breaker MOAB #1 MOAB #2 Tie MOAB South Breaker 21

22 FISR Status and Successes DMS FISR automation is currently deployed to all feeders. FISR events are happening on a daily basis. On July 18 th storm customers automatically Restoration time for FISR action averages about 3 minutes. Since beginning of rollout ~ 130,000 customers restored automatically 22

23 Managing Change Field Crews Road Shows Described function and benefits to field forces Higher level of sophistication Significant number of features Ensure sensor accuracy Ensure communications Manage programming FISR operation Will be complete before the crew arrives. Review when it would be disabled white tag Restrictive Reclosing on a feeder FISR auto-disable 23

24 Managing Change - Operators Operator Training Continuous Training and Feedback between Operators and the engineering team Run FISR in advisory to gain experience & view suggested switching prior to moving to closed loop Tagging Human performance Hot line tags 24

25 Future Smart Grid Initiatives FISR parameters Enhanced breaker SCADA, protection validation, sub outages, look ahead Single phase operation Take a 3 phase outage for crew to make repairs Integrate Smart Meters power flow, voltage verification Enhance Distributed Energy Resources visualization and management. Integration of solar sources Storage units Micro-Grids / Controlled Islands Volt/Var Control Sub transformer LTC integration Feeder capacitor control 25

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