1. EE379K/EE394V Smart Grids: Advanced Metering
Jonathan Pettit, PE
Oncor Electric Delivery
Ross Baldick, Department of Electrical and Computer Engineering
Spring 2017
Copyright © 2017

2. Outline Advanced Meters in Texas Advanced Meter Technology RF Mesh
Meter Data Flow
Operational Impacts
Customer Interaction
Using Meter Data for Non-traditional Uses
Conclusion
Outline of agenda for lecture
Advanced Metering is all about automation
Copyright © 2017

3. Smart Meters are not…
How many engineers we have in here? – engineer joke

4. Oncor Electric Delivery
9/19/2018
Oncor Electric Delivery
Texas’ largest regulated transmission and distribution utility – 6th largest in the U.S.
117,000 miles of transmission and distribution lines
54,000 square miles of territory
7 million people
3.4 million meters
~ 100 customers (Retail Electric Providers – REPs)
~ 630 miles
~ 390 miles
T&D company – no retail & no generation
7,000,000 customers
2,000,000 poles
1,000,000 transformers
The only way a traditional electric utility makes money (only source of revenue) is by reading meters and then billing energy consumption.
Advanced metering and the smart grid are the biggest changes to our industry in the last 100 years.

5. AMS Background
Oncor’s AMS initiative evolved as a result of PUC regulations:
Oncor launches its automated meter reading initiative and begins replacing traditional meters with automated meters.
Texas Legislature approved HB 2129, encouraging the installation of
Advanced Metering Systems
2005
2007
The Public Utilities Commission of Texas (PUC) adopts its advanced meter ruling, including specific technical and functional requirements for meters.
Oncor’s automated meters are not compliant with the PUC’s new regulations and as a result, Oncor revises its automated meter reading initiative to become an advanced metering system that is PUC-compliant.
How did we get here?
Back in 2005, we started our automated meter (AMR) initiative. We put in 600,000 automated meters.
Then, the Texas Legislature passed a law that basically said, “We want advanced meters.”
In May 2007, the PUC issued a rule defining requirements for those meters. Requirements for cost recovery.
Our AMR meters were not compliant with the new requirements, so we cancelled the program and started AMS, with the PUC’s approval.
2008
The PUC approves Oncor’s AMS program filing, including a surcharge to recover implementation costs.

6. What makes a Smart Meter in Texas?
9/19/2018
What makes a Smart Meter in Texas?
Provides 15 minute interval data available on a historic “day after” basis
Demand side management opportunities
Ability to provide time-of-use signals to customers
Control of selected appliances and equipment via a home area network (HAN) using ZigBee Smart Energy Profile (SEP) Provide energy consumption information to consumers via in-home monitors
Ability to remotely disconnect/reconnect customers
Ability to get “on demand” readings of customer meters
Provide a common AMS web portal for customer, REP, or authorized third party, with access to historic customer data and HAN devices using SEP
AMS Surcharge allows cost recovery during system deployment and for 7 years following (through 2019)
Fully compliant with the technical requirements of Texas PUC rule
Estimated $800 million capital spend
Monthly rate of $2.19 per month for residential customers
Common portal smartmetertexas.com

7. Meter Options - Then One channel – kWh, analog
One read per month, manual
For a standard self-contained meter, i.e. residential
Pretty exciting here!
Over time, they ran slow incorrectly recording meter consumption
Have the ability to recover additional meter data, but you have to visit meter and use an optical probe (1132comm) at the meter
Analog meters led to digital meters, then to automated meter reading (AMR) via one-way “drive by” or RF wireless
Instrument rated – separate current transformers (CTs) and potential transformers (PTs) for larger commercial and industrial customers

8. Meter Options - Now Settings Programs Multiple channels available
Configurations
Ability to modify meter attributes
Software
Operating system
Metrology firmware
RF Mesh firmware
ZigBee firmware
Meter Capabilities
Solid State
15 minute interval data
96 readings per day
Two way communication
On demand reads
Remote disconnect capability
HAN enabled
“Energy management device”
Sensor
Radio Capabilities
RF Mesh
900 MHz
Multiple frequency hopping
Variable power settings
ZigBee
2.4 GHz
IEEE
Events
About 400 events
Outages
Restorations
Power Quality
Tampering / Fraud
Configurable
Log only
Advisory
Alarm
Lots of pieces now, the meter joins the computer age
Two-way communications is what defines advanced meters.  
With two-way you have the ability to “talk” to the meter, to query the meter for information, and the ability to receive acknowledgement and response messages.  
It allows us to remotely connect and disconnect meters
It allows you to ask the meter for advanced meter data remotely and to run diagnostics.  
It allows you to update the meter firmware, programs, and configurations remotely.  
Two-way allows you to use meters as sensor devices.

9. Meter Options - Now Radio Capabilities RF Mesh 900 MHz
Multiple frequency hopping
Variable power settings
ZigBee
2.4 GHz
IEEE
Options for advanced meter communications:
PLC – power line carrier, low frequency signal injection through AC lines, limited to bandwidth and frequency of transmission due to element overheating, very high cost for substation infrastructure
cellular – commercial mobile technology, point-to-point, limited by coverage and ongoing O&M costs for service providers
RF – radio frequency wireless, could be any band, licensed or unlicensed, most common is 900 MHz ( MHz), good bandwidth, meters now available in WiMax (limited deployment)
HAN wireless is commonly ZigBee. ZigBee is an , similar to bluetooth in the 2.4, it is low power and low frequency
low power consumption limits transmission distances to 10–100 meters line-of-sight, depending on power output and environmental characteristics
Another option would be Z-Wave
Both options are used in home automation systems these days

10. Meter Options - Now Meter Capabilities Solid State
15 minute interval data
96 readings per day
Two way communication
On demand reads
Remote disconnect capability
HAN enabled
“Energy management device”
Sensor
Solid state meters have been around for decades – so this is not new
Meter reads – register reads (normally midnight) and interval data (preset block – in Texas case 15 min)
Two-way – ability to poll meter and receive acknowledgement and response
Ability to query meter “on demand” for current readings and conditions
Residential level meters have a remote disconnect switch preventing need to dispatch personnel each time connect or disconnect required
Ability to transmit to local Home Area Network information regarding energy usage, providing customer ability to react to usage needs
Sensor – ability to monitor many other conditions available through the meter on secondary system conditions
Big Data – was 3.4 million lines of data per month, now 10 billion lines, 150 tB of data now, almost 6 trillion data points

11. Meter Options - Now Settings Programs Multiple channels available
Configurations
Ability to modify meter attributes
Software
Operating system
Metrology firmware
RF Mesh firmware
ZigBee firmware
Programming determines what data channels are sent back
Configurations are operating parameters (e.g. undervoltage sustained voltage time 30 seconds vs. 40 seconds)
Four pieces of software – all this info needs to be maintained in host systems

12. Meter Options - Now Events Over 400 events Outages Restorations
Power Quality
Tampering / Fraud
Configurable
Log only
Advisory
Alarm
Many events
- Categories like, security, metrology, communication, diagnostics, etc.
Data is real, no guessing
When did power really go out and when was power restored
Voltage momentaries, sags and swells – other conditions related to power quality
Ability to detect tampering and theft
Configuration to send data as it occurs – alarm
Advisory with periodic meter read pushes
Log only – need to poll meter individually
Meter self diagnosis – self check, then data can be remotely pulled

13. RF Mesh and Backhaul RF Mesh Network Backhaul Network Back Office
900 MHz
Backhaul Network
Satellite, microwave, cellular, fiber, and wide area network
Routers
Mounted on utility poles and street lights
Back Office
Collectors
Mounted on 70 ft. concrete poles
Four antennas on the top, and a control panel and backhaul communication box at the base
Normally located in substations, within substation fence
This is a simplified picture of the RF mesh:
It’s a 900 MHz proprietary network that uses meters or routers to get the signal to the collector.
The collectors are normally in substations so we have a power supply and can get the data to the back office, as shown here.
Self-healing – when there is a break in the network, the device seeks and finds another route to communicate back to the back office, the meter may also change as needed for a better reliable connection
IT Systems
RF Smart Meters
Installed in residential and commercial premises
Meter-to-meter communication
RF Mesh
900 MHz radios
1 W transmitter / receiver
Self-healing network
Auto registering devices
Network can be shared with distribution automation devices
Router
Collector

14. Meter Data Flow 1 3 4 2 Read the Validate the Transmit the Meter
On-Demand Reads via In-Home Monitor
LCIS
DATA
REPOSITORY
HAN
HAN
Bill-Cycle Meter Data
Smart Appliances
Meter
MDMS
Premise & Billing Data
Meter & Customer Account Data
Collect the
Meter Data
Daily Meter Reads & Interval Usage Data
RF Mesh Network
Meter Transactions
Meter & Customer Account Data
Interval & Register Data
HEAD END
AMS ODS
Market
Settlement
Data
Meter
Attributes
RF Mesh Network
Backhaul Network
Meter
Attributes
AMS MAXIMO
Meter Attributes
Router
Meter & Customer Account Data
Let’s discuss how the meter data gets from the meter to the market:
Again, we read the meter and that data flows inside your house and to the RF mesh, which is Landis+Gyr’s Gridstream network. L+G is our primary AMS vendor, supplying our meters and the related network equipment.
The second box shows the data flow through the mesh—it might be through multiple meters or a series of routers. Eventually it goes to a collector at a substation and to the Head End, the software application that controls the meter and provides a way for us to get the data back to the home office.
Once it’s at the back office, we validate and process the data through some of the applications shown here.
Then, we transmit the data to the parties that need it—in this case, ERCOT, REPs, and consumers.
Customer
Account
Data
REPs
Collector
Smart Meter Texas Portal 2
Individual
Account
Data
Oncor Internal Web Portal
Consumer

15. Meter Data Flow – Read the Meter
Advanced Meter:
Records energy usage at 15-minute intervals
Transmits meter data to the premise HAN device via ZigBee Smart Energy 1.0
Transmits meter data to Oncor via the RF Mesh network
In-home Monitor
Receives meter data from the HAN
Displays energy usage to the consumer in near real-time
Communicates with the HAN to manage smart appliances
Read the
Meter 1
On-Demand Reads via In-Home Display
Smart Appliances
Connect to the HAN via ZigBee Smart Energy 1.0
Projects underway to bring smart appliances to market
HAN
HAN
Smart Appliances
Meter
HAN wireless is commonly ZigBee. ZigBee is an , similar to Bluetooth in the 2.4, it is low power and low frequency
 low power consumption limits transmission distances to 10–100 meters line-of-sight, depending on power output and environmental characteristics
An important note on the HAN. There are only a few production HAN devices available today for an individual to order, most come in from a energy management program. Oncor has a validation testing program and has passed around 60, with about twice that tested
RF Mesh Network
Home Area Network (HAN):
Receives energy usage data from the advanced meter
Sends meter data to the HAN device
Communicates with smart appliances
RF Mesh Network:
Receives meter data
Sends meter data to the router

16. Meter Data Flow – Collect the Meter Data
Router:
Receives meter data from the RF Mesh network
Forwards meter data to the appropriate collector
Backhaul Network:
Uses wide area network (WAN), fiber, microwave, or cellular components
Forwards meter data to Head End
Collect the
Meter Data
RF Mesh Network
Daily Meter Reads & Interval Usage Data
Meter Transactions
Head End:
Collects meter data
Receives meter attributes from AMS Maximo
Forwards meter data to the Meter Data Management System (MDMS)
HEAD END
RF Mesh Network
Backhaul Network
Meter
Attributes
Router
Collector
The router acts like a cell phone tower—sending the signal where it needs to be relayed.
As many as 10,000 to 15,000 meters could route signals to a single collector. From there, the data is sent to the backhaul network and the back office, as shown here.
Again, Head End is the vendor software that talks to and controls the meter. 2
Collector:
Receives meter data from the router via the RF Mesh network
Forwards meter data to Head End via the Backhaul network

17. Meter Data Flow – Validate the Meter Data
Meter Data Management System (MDMS):
Receives the meter data from Head End
Receives meter attributes from AMS Maximo
Validates the accuracy and completeness of the meter reads through the process of validation, estimating, and editing (VEE)
Provides estimates for any missing interval data
Creates billing-quality data
Sends bill-cycle meter data to LCIS
Sends interval and register data to the AMS ODS database
Customer Information System (CIS):
Receives bill-cycle meter data from MDMS
Receives meter attributes from AMS Maximo
Ensures meter data complies with business rules
Creates billing files
Sends premise and billing data to AMS ODS
Validate the
Meter Data 3
CIS
Bill-Cycle Meter Data
MDMS
AMS Operational Data Stores (ODS):
Receives interval and register data from MDMS
Receives premise and billing data from LCIS
Integrates interval data and billing data to make analysis and reporting easier
Sends meter and customer account data to the internal Web portal and the data repository
Premise & Billing Data
Meter & Customer Account Data
Interval & Register Data
AMS ODS
Meter
Attributes
MDMS does the validating and produces billing-quality data.
LCIS provides the premise and billing data.
AMS ODS provides our long-term storage and provides data for reporting.
AMS Maximo manages our assets.
Our internal Web portal is used for reporting and analysis.
AMS MAXIMO
Meter Attributes
Meter & Customer Account Data
AMS Maximo:
Maintains asset information and associated equipment
Sends meter attributes to MDMS and AMS ODS
Oncor Internal Web Portal:
Receives the meter data from AMS ODS
Provides data for internal reporting and analysis
Oncor Internal Web Portal

18. Meter Data Flow – Transmit the Meter Data4
Data Repository:
Receives the meter data from AMS ODS
Organizes and stores the meter data by REP
Sends account data to the Smart Meter Texas Portal
ERCOT: Uses the market settlement data to assess administrative fees, publish billing statements, and resolve disputes
DATA
REPOSITORY
Meter & Customer Account Data
REPs: Use the customer account data to bill customers, manage customer accounts, and support innovative new programs and pricing options
Market
Settlement
Data
Smart Meter Texas Portal:
Provides self-service market settlement data to ERCOT
Provides self-service customer account data to REPs and authorized third parties
Provides self-service individual account data to consumers
Once the meter data is valid and bill quality, we store it a data repository that can be accessed through the customer portal or Web services, which allows the REPs or ERCOT to access large amounts of data and register HAN devices.
Customer
Account
Data
REPs
Smart Meter Texas Portal
Consumers: Use their account data to make more informed choices about energy use
Individual
Account
Data
Consumer

19. 9/19/2018
Operational Impacts
From March 2009 through Dec 2016, Oncor has completed almost 17 million service orders remotely, instead of having to dispatch personnel and vehicles to perform these tasks.  Conservatively, this has eliminated the need to drive over 114 million miles, saving almost 9.5 million gallons of fuel, preventing over 92,625 tons of CO2 from being released into the environment.
In 2015, Oncor’s AMS processed 4.5 million service orders remotely with a 98.56% success rate, resulting in only 1.2% truck rolls. In 2016, there were 4.2 million remote service orders at a 98.78% success rate and only 1.4% truck rolls
In 2016, Oncor averaging 363,000 AMS service orders a month. Of these orders, 96,500 are Pre-Pay Disconnects and Reconnects.
Savings assumptions:
5 miles per service order
12 miles per gallon
19.5 lbs of CO2 per gallon
Opt-Out for advanced meters 267
Reduced employee injuries by 96% and preventable vehicle accidents by 88%.
Increased tampering identification/investigations.
Increase distribution operational efficiencies.
Service orders include:
Move-Outs
Move-Ins
Disc for Non Pay
Recon for Non Pay
Rereads
Switches
Safety Stats :
76 PVA’s in 2009 vs. 9 PVA’s in 2013
(Rate 4.95 to .96)
24 DART’s in 2009 vs. 1 DART in 2013
(Rate 2.18 to .20)
Seven years ago (before advanced meters were installed in Oncor’s service territory), the standard move-in charge cost $18; today it costs $2.26.
A priority move-in (a move-in request prioritized by a quick timeline) charge cost $97 in Today, that amount has dropped to $2.47 – a 97% decrease.
A meter connected on a holiday, it cost $123 in 2007 and was subject to scheduling by Oncor based on technician availability. Today, it costs $4.07 to remotely connect service, and it happens within hours.
Overall, from a meter-related discretionary service perspective, full installation of advanced meters has reduced the cost to customers by $35 million annually.

20. Smart Meter Texas Portal
Historic 15 minute interval usage data
HAN device provisioning
On demand read
Smart Meter Texas Portal
Customers
Separate GUIs
Wires Company’s
REPs
Historic 15 minute interval usage data
HAN device provisioning
HAN messaging
On demand read
API
Smart Meter Texas – smartmetertexas.com
NOTE:
GUI - Graphical User Interface
API - Application Programming Interface
HAN - Home Area Network

21. Smart Meter Texas Customer visibility of data Data available:
15 min. interval data
Daily register reads
Billed consumption
Ability to make an On Demand Read
Ability to download data
Ability to provision or deprovision HAN devices
Every customer in deregulated part of Texas can create account
Copyright © 2017

22. AMS and OMS
At the onset of an outage
Meters send a message after a 40 second outage
AMS filters the message
Ensures at least two meters on a transformer detects the outage
Reduces electronic traffic to the OMS
AMS sends filtered outage signals to OMS (faster and more dependable than customer calls)
OMS – outage management system
Includes a series of conditions, timers, and filters to minimize any false outages
25% of the time, problem is resolved before customer calls
On Demand Read of meter to check line & load side voltage before rolling maintenance truck
Once restoration is completed, the system sends us a notification
On customer initiated outage calls, operators will validate
Oncor’s service to the meter by on demand read

23. Power Quality Events received indicate a problem
Sometimes a meter, many times an indication of a problem on the distribution network
Common issues
Bad or loose connection
Transformer issue
Required a change to field resources training
Planned outage less expensive than equipment failure
Trust the data

24. Tampering / Theft (Revenue Protection)
AMS Meter Data
DFNP w/lost & no midnight read
Zero Consumption
Negative KWH
240 Load Volts
Reverse Rotation
Estimated Lost
Data analytics to detect theft
Estimated Lost – Based on an estimated loss for three consecutive days/Loss should be bounced off OMS - This data is obtained from the daily non-comm service order process. If the meter has been estimating for three days or longer, is in LOST status, and is not cut at a higher level then a tampering order is created.
Reverse Rotation – Communicating reverse rotation - L&G sends out a daily report identifying meters that have had reverse rotation detected or a tamper attempt suspected meter event occur. The next step is filtering out the legitimate reverse rotation (DRG meters, pump jacks, meters previously identified for legitimate usage).
240 Load Volts – Disconnected with 240 load volts on the load side - IBM Command Center Support team sends out a daily report of every meter in the disconnected switch status and the voltage received from when the remote disconnect occurred. This information is pulled from the database. A tampering order is sent out for every meter that has 240 voltage on the load side and line side.
Negative KWH – Registering negative KWH - This process uses the negative consumption report that is produced weekly by Cognos. Orders are sent to the field after removing oil field accounts and premises with orders already created. The remainder is reviewed individually in LCIS.
Zero Consumption - Registering zero consumption - Data management sends out a daily report that identifies any meter that had consumption on it in the past 7 days and then dropped to zero daily usage and did not have a disconnect on the meter. The list is then filtered down based on four days of continuous zero consumption, customer name, and premise description. AMS looks at the remaining meters individually and identifies the meters that have an alternating pattern where there have been multiple days of zero consumption.
DFNP w/lost & no midnight read - DFNP with no midnight read and the meter went into lost status - Operations support sends out a daily report that lists every remotely disconnected meter and its reading at the time of disconnect for the previous seven days. The reading is then compared to the most current midnight reading. If there has been more than 1 KWH of consumption since the disconnect and no other tampering order has been created on the account, then a METR order is created to do a meter test. If there was no midnight reading and the meter is not in the LOST status, an on-demand read is sent to each meter to validate consumption and two-way communication. If there is no response from the on-demand read, a tampering order is created. If the meter is in LOST status and the premise is not cut at a higher level, then a tampering order is created.

25. Monitoring meters per distribution transformer Benefits:
Asset Health
Monitoring meters per distribution transformer
Benefits:
Reduced outage time
Reduced overtime
Maintenance during normal business hours
Replaced before the customer was affected – no customer call
Predictive maintenance analysis
correlation of instantaneous voltages on individual meters on a transformer
Transformer winding damage – validated through TTR testing
Voltage regulation issues
Regulator or regulator control
LTC or control
Capacitor
Load imbalance
Damaged Meter
The benefits of this program include:
Reduced outage time (planned vs. reactive maintenance)
Reduced overtime
Transformers replaced during normal business hours
Replaced before the customer was affected – no customer call
Copyright © 2017

26. AMS as SCADA Interactive One-Line Schematic:
Fault Indication
As-operated system configuration
AMS Meter data pushed every 5 minutes
Meter, three phase voltages and currents, Timestamp of last push, and customer
Ability to request the above meter data for all downstream meters or all meters attached to the selected device
Ability to determine the configuration of customer owned, automatic transfer switches, or split bus equipment using AMS meters
SCADA – system control and data acquisition
Simple Case
Feeder B trips
Local SCADA system suffers an outage as well
Status of Switchgear & ATO are unknown
Did the ATO throw-over?
Typical ping of Meter 1 will report it is healthy, but this does not verify if it is carrying load
Polling Meter 1 for voltage & current (or KW) will verify if ATO threw over.
Voltage but no current -> ATO did NOT throw over
Voltage & current -> ATO did throw over
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27. System Reliability
With sensors on every premise, data is collected for any electrical service change
Meter interval data, outage and restoration notifications
Near future: ability to calculate more accurate distribution system reliability
Perhaps the most important utility measurement – how reliable is a utility system?
SAIDI - System Average Interruption Duration Index (SAIDI) – ANSI standard for measurement
Advanced meters provides the means to calculate a reliability number based on actual individual customer meters
Currently, these calculations are done at a SCADA level – substation level and assumptions are made with confirmations by customer call and other indicators
This is still in development
Copyright © 2017

28. Summary
An advanced metering system (AMS) brings a lot more than just the ability to read meters remotely. AMS enables a whole new set of data that can be used for engineering analysis and provide for new ways to improve a distribution system’s efficiency and reliability.
Other examples: load flow analysis (used to be done as a calculation once a year, now have real data every day)
Advanced meters can feed power outages and restorations to an outage management system allowing power company response teams to respond to outages without requiring customer calls.  
Meters send events that provide indication of other distribution system problems (power quality), such as loose connections, bad terminations, or possible transformer issues.  
Meters can provide indication of distribution asset health or transformer overloading on a real time basis.  
Tampering and theft can be identified based on multiple algorithms.  
Meters can be used as sensors providing SCADA-like indications for feeding operator responses.  
Finally, meters provide real data as to the reliability of a distribution system.
Copyright © 2017

29. Homework Exercise: Due Thursday, March 91.
Describe the three common technologies used in advanced metering communications.
Describe why two-way communication is so important in advanced metering.
Describe some ways that advanced meters can be used for more than customer usage billing.
Copyright © 2017