Utilizing AMI Infrastructure to Support Distribution Automation - PowerPoint PPT Presentation

Utilizing AMI Infrastructure to Support Distribution Automation Applications Smart Grid Distribution Automation Conference Nov. 2-3, 2011, Raleigh, NC

History Lesson "Load/voltage modeling of distribution systems; a system identification approach," Gorman, M.J.; Civanlar, S. ; (Grainger, J) Southeastcon '89. Proceedings. Energy and Information Technologies in the Southeast., IEEE , vol., no., pp.386-389 vol.1, 9-12 Apr 1989 Abstract: A system identification method is proposed which can be used to characterize the distribution system load as a function of the substation voltage. The primary objective of this technique is to capture the dynamic variation of the composite system load on distribution feeders so that the most effective substation voltage level can be obtained and applied to conserve energy over specified control periods. The proposed system identification method is implementable on actual distribution systems by utilizing existing capabilities of the distribution automation hardware. Also, the impulse response of a space heating load is identified using the proposed technique to demonstrate the applicability of the identification method. 1

Volt/VAR Researcher in Spotlight  Libya October 31: Libya's interim authorities have named Tripoli academic Abdurrahim al-Keib as the new prime minister.  Papers – listed as El-Kib  Grainger interview: http://www.alumniblog.ncsu.edu/2011/11/02/nc-state-professor- recalls-student-who-now-leads-libya/ 2

Topics  Volt/VAR Control Retrofit Paths  Utilization of “AMI Infrastructure”  Enhancing Meter Functionality  Considerations for realizing a set of bellwether voltage metering functions – Operational – Nonoperational  Bellwether meter configuration and reporting  Conclusions 3

Volt/VAR Retrofit Paths  How to proceed with different starting points as far as existing level of automation?  What about the small utilities, munis, coops (3000 entities)?  What type of Volt/VAR control makes sense for: – A 5,000 meter utility? – A 25,000 meter utility? – A 250,000 meter utility?  How should need for scalable solution approaches impact AMI/DA product offerings?  Can AMI Infrastructure installation facilitate a “DA Catch Up”? 4

Possible Starting Point  No top of feeder measurements, non-microprocessor-based relay  Switched capacitors sparingly used  Power factor not properly corrected  Possible voltage regulation problems  Local control on switched capacitor, no upgrade path for communications or remote control  Local control on substation and line regulators, no options for remote control 5

Adding the Substation Automation  Install basic substation automation components  Upgrade feeder relay to microprocessor- based – get richer set of feeder measurements  Upgrade voltage regulator control – SCADA compatible  Add substation points to Supervisory Control and Data Acquisition (SCADA) or historian 6

Upgrading Feeder Controls  Upgrade feeder Substation controls  Install Switched Voltage Voltage Capacitor Regulator Regulator Control Control Radios Feeder Regulator Relay Control  Link to DA Radio DA Radio Module Module Head End Substation Gateway/PLC for collecting data SCADA DA Head End  Interface to SCADA 7

DA Endpoints  DA endpoints need to support a Intelligent MicroRTU wide variety of Electronic Device automation Communications applications Module (greenfield and retrofit)  Need flexibility on communications type (ex. Licensed Capacitor Fault Current Radio and Cellular Indicator Bank versions) Control Receiver  Faceplates? 8

DA Radio Module Interface Example  DA Radio Direct Pass Through Module mounted on SCADA Connection inside of cabinet. DA Radio DA Device Module Controller  SCADA connection (via DNP) for data monitoring and remote switch control.  Pass Through for device configuration program. 9

Enabling Volt/VAR (DA Only)  Addition of End of Line voltage measurements  Decentralized or Centralized Control  Engineering effort for model building, configuration and testing  How many EOL points are needed? 10

Voltage Range Targets  Allowable Voltages defined by Voltage 128 ANSI Standard C 84.1 – 1995 “Electrical Power Systems and 126 Equipment – Voltage Ratings.” 124 Typical Range  Feeder Voltages typically at 122 A Service A Utilization high end of utilization range. 120 VVC Range  Volt/VAR control used to both 118 drop utilization voltage and 116 narrow voltage deviation 114 range. 112  Meter measurements could 110 ensure that limits not violated. 108 11

Volt/VAR with AMI Infrastructure  DA Radio Modules provide communications interfaces to capacitor controls, line regulator controls, etc.  DA head end links endpoints with SCADA and Volt/VAR Control.  Bellwether meters provide voltage data to AMI head end.  AMI head end that receives voltage data from bellwether meters and forwards this data to the target Distribution Management System application(s). 12

AMI/DA Channelization Scheme  Licensed RF  Multi-Channel Base Stations  Concurrent Parallel Channels  Electric, Water, Gas & DA AMI Poll AMI Normal Read DA  DA Traffic put on channels Poll separate from AMI to avoid DA Normal traffic degradation Read ALARM 13

Enhancing Meter Functionality  Traditional meter functionality is measurement of Energy (kWh), Peak kW, Reactive Power (kVAR), interval data, instantaneous voltage ping.  Meter has enough processing power to perform other measurement functions.  Voltage samples can be processed to: – Voltage averages over longer defined intervals (seconds to minutes). – Voltage averages/minimum/maximums over defined intervals. – Voltage power quality sags and swells magnitudes and durations. 14

Data Types  Operational – Time-Schedule Reporting – Report on Exception – Unsolicited Alarm Reporting  Nonoperational – Voltage Interval Data – Voltage Power Quality Data 15

Time-Scheduled Reporting  Voltage averages over a predefined interval at a fixed report frequency  Ex. (1:01:13; 122.5V), (1:06:22; 122.4),(1:011:11, 121.9)  Uplink only, no acknowledgement from head end 125 124.5 Example of intermittent 124 voltage due to photovoltaics 123.5 5 Min Ave Xmit 10 Sec 123 5 Min Max 122.5 5 Min Min 122 16

Report on Exception  Only send voltage if change exceeds a threshold change to reduce traffic  Ex. (1:01:13; 122.5V), (1:011:11, 121.9)  Send “heartbeat” report to verify meter still communicating  Advantage is reduction in communications traffic 17

Unsolicited Alarm Reporting  Only send voltage data (or just alarm) if value goes below or above threshold  Ex. (1:01:15; 118V)  If only alarm status set, can follow up with voltage ping 18

Voltage Interval Data  Provide distribution planners with indication of where voltage problems are occurring with time stamps  Voltages calculated over predefined window (ex. 1 minute) – need window compatible with evaluating volt/VAR control  Voltage average, minimum and maximum over fixed interval, such as 1 hour  Transmit voltage interval data every 24 hours 19

Voltage Power Quality Data  Provide distribution engineers with voltage quality data  Trigger meter recording on voltage sags and swells  Compute voltage sag/swell magnitude, duration with timestamp  Transmit on threshold or hold for predefined time period 1 0.5 Voltage (pu) 0 -0.5 -1 0.02 0.04 0.06 0.08 0.1 0 Time (sec) 20

Bellwether Meter Configuration & Reporting Cryptography Keys Measurement Meter Data Data Archiving Messages AMI Backhaul Transceiver Client AMI Electric Distribution Head End Bellwether Meter Management Provisioning System Firewall Messages Application Bellwether Meter Configuration User Interface Firewall for Bellwether Configuration  Bellwether meters are user selectable (ex. 1 or 2 meters per lateral).  Assume small number (1-2%) of meters utilized for near real-time feedback.  Measurement data routed to volt/VAR client application. 21

Advantages of Bellwether Functionality  Minimize need for expensive End of Line feeder measurements.  Can easily relocate bellwether meter points.  Voltage interval data can be utilized to: – Plan for location of bellwether points – Determine if voltage violations are already occurring – Evaluate effectiveness of control scheme  Have more confidence in setting lower voltage targets if can be assured that violations are not occurring.  Use of a large of measurements might allow for simpler control strategies. 22

Summary  New to Volt/VAR Control? – Consider spending some time in the library.  More to Volt/VAR control than just radios and logic, need to consider complete infrastructure build-up and other supporting solution components.  Need to factor in the potential synergy between AMI projects and Volt/VAR control – it’s more than just a DA app.  Meters are more than cash registers and outage detection devices – a great deal of potential sensor input still waiting to be tapped. 23

QUESTIONS? 24