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Estandares de medición “inteligente” para lograr
interoperabilidad
Smart Grids Latin America 2008, Santiago, Chile
Mariano Michael Bergman
ITRON - Marketing and B&D Manager – Electricity – LAM
Mariano.Bergman@itron.com
Campinas – Brazil
Presentation Contents:
� Interoperability
� Definition
� Market Drivers / Overview
� Different Levels of Interoperability� Mechanical
� Electrical
� Functionalities
� AMR - Communication� AMR - Communication
� AMI – Communication
� AMI - Interoperability� Definition
� Market Overview
� Standards Types� IEC, ANSI, proprietary
� Conclusion
Smart Grids Latin America 2008, Santiago, Chile
Interoperability :
� Definition: Is a property referring to the ability of
diverse systems to work together (inter-operate).
The IEEE defines interoperability as:
the ability of two or more systems or components to
exchange information and to use the information that
has been exchanged.has been exchanged.
�Interoperability is key:
� Protects large capital investment
� No vendor can deliver the “best” entire solution
� Simplifies “technology refresh”
Smart Grids Latin America 2008, Santiago, Chile
Market Drivers towards Interoperability
� Market liberalization and global competition created a
complex environment and new needs for meter data collection,
exchange and usage.
� Energy providers, focusing on improving O&M efficiency, � Energy providers, focusing on improving O&M efficiency,
revenue collection, customer satisfaction, reducing non
technical and technical losses and striving to optimize the use of
their resources, need metering systems that provide more data,
more often, from geographically dispersed locations.
� Accurate data on time, securely, with the lowest possible
overall cost are needed.
Smart Grids Latin America 2008, Santiago, Chile
� Types and Levels of INTEROPERABILITY
� Mechanical
� Electrical
� Functions
� Communication AMR� Communication AMR
� Communication AMI
Smart Grids Latin America 2008, Santiago, Chile
Two main worlds for Electricity
• IEC International Electrical Committee
- The largest territories (Except NAM)
- Regional customization CENELEC (Europe)
• UTE France, VDEW Germany, British standard …
6
• ANSI family
- North America US, Canadian standards
- Part of Central & South America
- Caribbean and part of Pacific area
IEC : Terminal box, Indoor
ANSI : Meter socket, Out door
Mechanical (Dimensions and Connections)
Symmetrical connection
Asymmetrical (DIN type) connection
ELECTRICAL
All world in one continent
LAM
SP - 2W and 3W
PP - 3W 4W Delta YPP - 3W 4W Delta Y
Voltages: 120 V and 230 V
Frequency: 60Hz 50Hz
Internationsl Standards: ANSI, IEC
National Standards: ...
Smart Grids Latin America 2008, Santiago, Chile
Meter Functions
(Residential / C&I)
Billing:� kWh
� kVarh
� PF
Non Billing:� I / V / F /
� Mass Memory
� Anti Tampering � PF
� Máx. Demand
� 15 / 30 min
� Anti Tampering
Functions.
Smart Grids Latin America 2008, Santiago, Chile
Meter Communication
Mechanical Registers + Display
First communication to the meter was done through the mechanical
register that at the beginning was done with pointer so the meter
reader could draw instead of write the numbers. With the static
meters introduction of new information must be communicated through
an LCD type display.
Optical / Electrical Port + HHU
Applied to direct local data exchange. Meter reader connects a hand-
held unit (HHU) to a meter or group of meters to download the
information. More recently with the advent of AMR the local
communication is only used for back up reading and for
reprogramming the meter in the field
IEC 62056-21 / FLAG (Direct local data exchange) describes
hardware and protocol specifications for local meter data exchange.
The protocol permits tariff devices to be read and programmed. It is
designed to be particularly suitable for the environment of electricity
metering, especially as regards electrical isolation and data security.
Meter Communication
Optical / Electrical Port + HHU
IEC 62 056-31 EURIDIS working with twisted pair cables for local
or remote reading of residential meters. The basic EURIDIS solution
uses a field bus for communication. Each meter is linked to the
EURIDIS local bus, which consists of a two-wire cable connected to a
magnetic coupler, generally located in the public domain. The operator
simply connects a handheld unit to the magnetic coupler so that it can
read each meter safely.
ANSI C12.18-2006 details the criteria required for communications
between a C12.18 device and a C12.18 client via an optical port. The
C12.18 client may be a handheld reader, a portable computer, a master
station system or some other electronic communications device. This
standard establishes protocol specifications and provides an open-
platform communications protocol for two-way communication with a
metering device through an ANSI Type 2 optical port.
Several Local Standards
Smart Grids Latin America 2008, Santiago, Chile
AMRAMR
Communication - AMR
Fixed Network
Meter Reading
Tra
nsf
orm
ati
on
Meter Reading
Utility and Customer Benefits
Technology
Integration
Mobile
Meter
Reading
Handheld
Meter
Reading
Co
sts
–V
alu
e C
ha
in
Simple consumption read Distribution ReliabilityInterval Meter Data
Co
st p
er
rea
dT
ran
sfo
rma
tio
n
Security
Operational Efficiency
Revenue Cycle Improvement
Lower Meter Reading Costs
Revenue Protection
Outage/Restoration Notification
Voluntary TOU
Meter Communication - AMR
AMR (Walk-By, Dive By, Fixed Network)
Meter Communication - AMR
AMR - Walk-By
Data Collection by Handheld Computer
This lets meter readers gather data from Static meters or Mechanical meters equipped
with ERTs without directly accessing the meter or the premises. The same handheld
computer can read any combination of electric, gas and water meter modules as the
meter reader walks the route. Back at the office, meter readers plug their computers into meter reader walks the route. Back at the office, meter readers plug their computers into
the utility’s network for automated uploading of gathered data and downloading of the
next day’s routes.
A meter reader using a radio-equipped handheld computer can read anywhere from 600
to 1000 meters in a typical day. significantly more than with a system based on manual
data entry. Utilities switching to automated meter reading with handheld computers can
see cost reductions coupled with more accurate and timely billing, which helps with
revenues. This method works well for small- to mid-sized utilities and those planning a
slower transition away from completely manual meter reading.
Smart Grids Latin America 2008, Santiago, Chile
Meter Communication - AMR
AMR - Drive By
Data Collection by Mobile Collector
For larger-scale automatic meter reading, utilities can equip vehicles with portable computers and
radio transceivers meters. The speed of a car or van, compared to a meter reader on foot,
dramatically improves meter reading frequency. That increased frequency gives utilities more
possibilities to use data for saving costs and improving operations.
While the meter reader drives the mobile collection vehicle along its route, the radio transceiver While the meter reader drives the mobile collection vehicle along its route, the radio transceiver
gathers data from meters within a radius of up to 900 meters. At the end of the day, the gathered
data are uploaded to the billing system for bill generation and the next day’s route downloaded.
Mobile data collections systems now come with state-of-the-art GPS mapping systems that let
users “see” their data collection process and analyze any missed readings before leaving a route.
Once the route has been completed and the meter reader has returned to the office, the system
administrator can then play back the route that was driven to identify opportunities to optimize
routes and improve meter reading.
Mobile data gathering excels in a variety of environments. A single transceiver will read an average
of 10,000 to 12,000 meters in an 8-hour shift with a single service, depending on meter density and
system use. Mobile collection can also save time and costs in rural and industrial areas where
meters may be too distant, difficult, or dangerous to reach effectively on foot.
Meter Communication - AMR
AMR - Fixed Network
Reading by Fixed Network
Utilities install a fixed network of central collection units for automatic meter reading. A
central collection unit consists of a radio transceiver mounted on a pole, tower, or building
gathering data from the meters within its radio reception range. Phone lines, IP, gathering data from the meters within its radio reception range. Phone lines, IP,
broadband, cellular, or other data connections provide communications with the utility.
This permanently-installed data collection equipment gives utilities incredible
opportunity and flexibility, including identifying electric service outages and restoration.
Some utilities use a fixed network in more densely populated urban areas where high
energy consumption and high account turnover in multiple-occupant buildings makes on-
demand meter reading desirable. Other utilities install a fixed network in their service
area when they need to gather very frequent readings to help with operational
improvements. The amount of data that fixed networks can generate only truly
becomes useful with the right data management and knowledge applications to analyze
that data.
Market Overview
• Enabling technologies, like low-cost A/D converters, microcontrollers, DSP-s, high capacity memories and latest communication methods are driving a revolution started some 30 years ago in a conservative industry, dominated for more than a century by electromechanical meters and manual meter reading meters and manual meter reading
• Since 2006, interest in smart metering and advanced metering infrastructure (AMI) has rapidly accelerated
Smart Grids Latin America 2008, Santiago, Chile
AMIAMI
Smart Grid
Communication - AMI
Open Standards,
Tra
nsf
orm
ati
on
Moving from AMR to AMI
AMRAMR
Open Standards,
Two-way
Communications
to smart meter
Fixed Network
Meter Reading
Utility and Customer Benefits
Technology
Integration
Mobile
Meter
ReadingHandheld
Meter
ReadingCo
sts
–V
alu
e C
ha
in
Simple consumption read Distribution ReliabilityInterval Meter Data
Co
st p
er
rea
dT
ran
sfo
rma
tio
n
Low Meter Reading Costs
Operational Efficiency
Revenue Cycle Improvement
Security
Revenue Protection
Outage/Restoration Notification
Voluntary TOU
CPP Rates
Mandatory Time Based Rates
Remote Disconnect/prepayment
Mass Market Demand Response
Home Automation
Distribution Management
AMI
• Advanced Metering Infrastructure (AMI):
An architecture of smart meters and advanced two-way communications providing essential infrastructure and information to:
– Reduce Technical and Non Technical Losses.
– Improve Revenue Collection – Help consumers – Improve Revenue Collection – Help consumers pay their bills.
– Empower customer participation in managing their energy usage and conservation
– Improve efficiency and reduce utility general O&M cost
AMI must deliver AMR functionality and
improved revenue performance
Smart Grids Latin America 2008, Santiago, Chile
LOSSES - SAM
LAM / SAM - Main DRIVERS
LOSSES - SAM
� Main causes of Non Technical Losses (NTL) :� Metering tampering (inside the meter)
� Outside the Meter (direct connection, by pass,…)
� Meters outside of metrology range (old meters)
� Revenue Collection Losses (RCL) :� Bad payers
� By example / habit
� Low income / manage consumption
� Reading errors (un volunteered / volunteered)
� Commercial Errors
Source CIER
LAM – SAM Main DRIVERS
Sleeping MetersDirect Connections
Fraude MktMeter by pass Hold Disk
Remote Control Fraud"We have a device that takes the electricity coming into your house and sends it back to the
power company so your meter reads nothing!" All the "electricity" that enters your house IS
returned to the power company! That's why it takes two wires to complete a "circuit".
On top of RAS there are OTHER ECONOMIC BENEFITS:
� Reading Cost � Complex Tariffs� Spot pricing
Revenue Assurance Solutions (RAS) are based AMI systems
with a more customized approach to Losses.
� Spot pricing� MM Data� Load Control� Power Quality (DEC / FEC)� Special Readings� Reduce General O & M Costs � Increase average meters reading per day� Eliminate estimated reads � Fewer employee injuries / motor vehicle accidents � Reduce customer calls to the Call Center� Reduce damage to customer property� Exceed service quality standards for meters read� Outage detection and recovery capabilities� Increase customer quality of services awareness
AMI - INTEROPERABILITY
Crear
Medición
E. Eléctica
Recolectar
Handhelds
UtilizarAdministrar
MDM
Informar /
Controlar
SCADA
ERP
Medición
E. Gas
Medición
agua
Medición
E. Térmica
Concentradores
Rutas
MDC
Pronóstico
consumos
Optimización
De distribución
Sistema
protección
De la
facturaciónAtención clientes
MDM
Administración
Sistemas prepago
Billing
Information flowing upstream
Smart Grids Latin America 2008, Santiago, Chile
AMI: Enabling
Consumer Participation
Simple awareness
Direct load control
Price response
Demand response, conservation
Energy management
Manage
Control
Going “green”
Plug In cars
Inform
Solar
Going “green”
Information flowing downstream
� Legal (country dependant) MANDATORY
� Legal metrology (Financial transaction involved)
� Communications
Hierarchy of the standards
To operate this Systems Successfully
and with INTEROPERABILITY
you need STANDARDS
26
� Communications
� Environment
� National / International MANDATORY OR NOT standards
� Enclosure, terminals, environment, communications, security
� Utility´s own standards
� Large utility specifications (EDF, ENEL…)
� De facto industrial standard
� Communications protocol TCP/IP, GSM…
Smart Grids Latin America 2008, Santiago, Chile
� Open + International = ANSI / IEC
� Advantages: Implemented by most meter / systems manufacturers,
big customer base guaranties lower cost, interoperability and quality.
Development cost is spread over a large customer base. Standard
quality is robust since is reviewed buy a large technical community of
Utilities, Manufacturers and other organizations.
High level of interoperability.High level of interoperability.
� Disadvantages: Compromises have to be made at some level for
specific applications. One size doesn´t fit all. Can be more expensive
then a specific implementation.
NON MANDATORY STANDARDS
Smart Grids Latin America 2008, Santiago, Chile
� Proprietary (Utility) EDF / ENEL
� Advantages: Developed according to specific utility needs for the
best return on investment. Less compromise. Development cost is high
but spread over a large customer base (> 35 million). Product cost is
also kept low due to high volumes.
Highest level of interoperabilityHighest level of interoperability
� Disadvantages: Product Differentiation / Added Value is limited
since specifications are usually very rigid. Needs a strong technical and
financial commitment from the utility.
NON MANDATORY STANDARDS
Smart Grids Latin America 2008, Santiago, Chile
� Open + National
� Advantages: Usually based on International standards with local
customization to adapt to local needs. Adaptation cost is spread over
a medium customer base and usually is done locally.
Medium level of Interoperability
� Disadvantages: Customizations can introduce additional cost
(justify by the local application) and must be carefully defined and (justify by the local application) and must be carefully defined and
implemented in order to avoid losing overall robustness.
NON MANDATORY STANDARDS
Smart Grids Latin America 2008, Santiago, Chile
� Proprietary (Manufacturer)
� Advantages: Normally applied for communication, developed for
best product performance and cost. Lower product compromise…
Good for niche markets where some standards can bring a high
burden to the product. Can be a good solution when there is a strong
partnership between manufacturer and utility.
Low level of interoperability
� Disadvantages: Utility has to rely on less vendors (one).
NON MANDATORY STANDARDS
Smart Grids Latin America 2008, Santiago, Chile
� Adoption of ANSI C12.19 (meter data in standard tables)� Adoption driven by utility industry
� For many utilities, C12.19 data is already mandatory, mature
� ANSI C12.22 is the application layer protocol standard for AMI
Open Standards ANSI C12.XX
� ANSI C12.22 is the application layer protocol standard for AMI� Builds on ANSI C12.19
� Support structure ties in with other utility C12.xx standards
� Makes full provision for system interoperability
� Its development was meter-data centric
� Has followed a well considered evolution to its current form
� Offers network addressability & security at the application layer
� Independent regarding the communications technology chosen
Smart Grids Latin America 2008, Santiago, Chile
• C12.22 is an application or system protocol that provides for the transport of C12.19 data tables over any network medium. Its features include:– A methodology for both session and “session-less” communications
– A common data encryption and security model
– A common addressing mechanism for use over both proprietary and
C12.22 Features
– A common addressing mechanism for use over both proprietary and non-proprietary network mediums
– Interoperability among metering devices within a common communication environment
– System integration with 3rd-party devices through common interfaces and gateway abstraction (non-C12.22 compliant)
– Both two-way and one-way communications with end devices
Smart Grids Latin America 2008, Santiago, Chile
Open Standards IEC 62056-XX
DLMS: “Device Language Message specification” A generalized concept for abstract modeling of communication entities
COSEM: “COmpanion Specification for Energy Metering” Sets the rules, based on existing standards, for data exchange with energy meters
Smart Grids Latin America 2008, Santiago, Chile
�IEC 62056-21 (Direct local data exchange) describes hardware and protocol specifications for local
meter data exchange. In such systems, the operator connects a hand-held unit (HHU) or a unit with
equivalent functions to a tariff device or a group of devices.
� IEC 62056-62 (COSEM* interface classes) and IEC 62056-61 (OBIS*) describe an energy type, vendor-
and communication media independent model of the metering equipment. The COSEM model, object
oriented approach, working with objects close to the metering domain (like registers, profiles, clock,
schedules, communication setup and so forth), provides a standardized view of the data generated,
stored, displayed on and transmitted from the meter. The OBIS system provides a solution for identifying
all metering data in a standardized way. Through standardized ways to add new interface classes and
instances, the model supports innovation and competition while maintaining interoperability.
IEC Features
instances, the model supports innovation and competition while maintaining interoperability.
�IEC 62056-42 (Physical layer services and procedures), IEC 62056-46 (Data link layer using HDLC*
protocol) and IEC 62056-53 (COSEM application layer) describe a three-layer protocol stack, based on
the ISO/OSI model, to transport data to and from the meter using the COSEM model described above.
Interoperability is ensured through the possibility of negotiating features and parameters of each layer.
* COSEM: COmpanion Specification for Energy Metering
* DLMS: Distribution Line Message Specification
* HDLC: High-level Data Link Control
* OBIS: OBject Identification System)
HAN: ZigBee Smart Energy Profile
� ZigBee Smart Energy is an
open-standard application for
energy management.� Designed in conjunction with utilities and
manufacturers
� Tested and certified interoperability
ZigBee Smart Energy profile
� Tested and certified interoperability
� Smart Energy helps simplify, standardize,
and automate demand response and
energy conservation
� Certified devices for secure home-area
networks are available today
� Meters, thermostats, load control, outlets,
in-home displays
� Advanced smart metering standards
� ANSI C12.10 � C12.19 � C12.22
� IEC 62056 – XX
� Network communications� ZigBee® wireless networking
� HomePlug® powerline networking
� Public / private WAN:
OpenWay: Open Standards Architecture
Open standards support network-of-networks
� Public / private WAN:
� GPRS / 1xRTT / CDMA
� WiMax / Tropos / Arcadian
� Information technology standards
� Internet Protocol (IP)
� Service-Oriented Architecture (SOA)
� Extensible Mark-up Language (XML)
� Web Services Description Language (WSDL)
Smart Grids Latin America 2008, Santiago, Chile
Conclusion
� Interoperability is key�Protects large capital investment �No vendor can deliver the entire
solution� Simplifies “technology refresh”
� Why open standards?� Why open standards?�Deliver interoperability�Allow for application growth not
envisioned today�Best when focused at application layer�Any communication medium
can be used
Smart Grids Latin America 2008, Santiago, Chile
Thank You.
Mariano Michael Bergman
ITRON - Marketing and B&D Manager – Electricity – LAM
Mariano.Bergman@itron.com
Campinas – Brazil
To know more, start here: www.itron.com
Smart Grids Latin America 2008, Santiago, Chile
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