Analysis of Smart Metering projects

Work Package: WP2

Type of document: Deliverable

Date: 08/07/14

Energy Theme; Grant Agreement No 226369

Partners: EDSO4SG, RSE, ZABALA, CEIT, ENERGYLAB

Responsible: RSE

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Title: ANALYSIS OF SMART-METERING

PROJECTS (UPDATE 1)

Version: 1.3 Page: 1 / 97

Project Funded by the European Commission under the 7th Framework Programme

D 2.2

ANALYSIS OF SMART-METERING PROJECTS

(UPDATE)

© Copyright 2012 The Meter ON Consortium

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Date: 08/07/14


Title: ANALYSIS OF SMART-METERING PROJECTS (UPDATE

1)



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Document History

Vers. Issue Date Content and changes

1.0

1.1

1.2

1.3

09/05/2014

12/05/2014

21/05/2014

08/07/2014

Document sent to Management Board for revision

Document sent to project participants for last check

Document finalized and approved by Management Board

Minor changes applied and approved by the Management Board

Document Authors

Partners Contributors

RSE Renato Urban, Giuseppe Mauri

CEIT Alanova Wolfgang Wasserburger, Adela Marcoci

EnergyLAB Giacomo Di Foggia, Guido Micheli, Enrico Cagno

Enel Marco Baron

Document Approvers

Partners Approvers

Partner 1 Management Board

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TABLE OF CONTENTS

EXECUTIVE SUMMARY ..................................................................................................................................... 8

PURPOSE ......................................................................................................................................................... 9

1 INTRODUCTION ....................................................................................................................................... 9

2 OVERVIEW OF QUESTIONAIRE RESPONDING TO METER-ON ................................................................... 9

3 CASE STUDIES ........................................................................................................................................ 17

3.1 AUSTRIA ................................................................................................................................................. 17 3.1.1 EVN ................................................................................................................................................. 18

3.1.1.1 Technological analysis of the solution deployed .................................................................................... 19 3.1.1.2 Economic analysis of the solution deployed .......................................................................................... 21 3.1.1.3 Customer involvement ........................................................................................................................... 24 3.1.1.4 Other advanced solutions enabled by smart meters ............................................................................. 25

3.1.2 Stromnetz ........................................................................................................................................ 26 3.1.2.1 Technological analysis of the solution deployed .................................................................................... 27 3.1.2.2 Economic analysis of the solution deployed .......................................................................................... 28 3.1.2.3 Customer involvement ........................................................................................................................... 29 3.1.2.4 Other advanced solutions enabled by smart meters ............................................................................. 29

3.2 BELGIUM ................................................................................................................................................ 30 3.2.1 EANDIS ............................................................................................................................................ 32


3.3 FINLAND ................................................................................................................................................. 43 3.3.1 Fortum Sahkonsiirto Oy .................................................................................................................. 44


3.4 HUNGARY ............................................................................................................................................... 58 3.4.1 EDF Demasz .................................................................................................................................... 59


3.5 NETHERLANDS ......................................................................................................................................... 72 3.5.1 Enexis BV ......................................................................................................................................... 75


3.5.2 Liander ............................................................................................................................................ 82 3.5.2.1 Technological analysis of the solution deployed .................................................................................... 83 3.5.2.2 Economic analysis of the solution deployed .......................................................................................... 85 3.5.2.3 Customer involvement ........................................................................................................................... 86 3.5.2.4 Other advanced solutions enabled by smart meters ............................................................................. 88

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4 MAIN FINDINGS AND CONCLUSIONS ..................................................................................................... 92

COPYRIGHT .................................................................................................................................................... 97

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GLOSSARY AND ACRONYMS

AMM Advanced Metering Management

BEUC The European Consumer Organisation

CEN European Committee for Standardization

CENELEC European Committee for electrotechnical standardization

DG DNO

Distributed Generation Distribution Network Operator

DSO Distribution System Operator

EDSO European Distribution System Operators for Smart Grids

ESMIG European Smart Metering Industry Group

ETSI European Telecommunications Standards Institute

EV Electric Vehicles

GPRS General Packet Radio Service

GPS Global Positioning System

GSM Global System for Mobile Communications

HV,MV,LV High Voltage, Medium Voltage, Low Voltage

IEC International Electrotechnical Commission

Meter ON Supporting the development and deployment of advanced metering infrastructures in Europe

OBIS Object Identification System

PLC Power Line Communication

Prosumer A Customer who consumes as well as produces electricity

RF Radio Frequency

SG-CG Smart Grids Coordination Group

UTC Coordinated Universal Time

V2G Vehicle-to-Grid

V2H Vehicle-to-Home

WACC Weighted Average Cost Of Capital

WAN Wide Area Network

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REFERENCES

OPEN meter 2009 – Report on regulatory requirements, FP7 project,

http://tinyurl.com/nkmhv7g last accessed 21.2.2013

ERCEG 2011 – Final Guidelines of Good Practice on Regulatory Aspects of Smart Metering

for Electricity and Gas http://tinyurl.com/p9s2qht last accessed 19.02.2013

OFGEM 2011 – Vulnerable customer research by FDS International

http://tinyurl.com/pbh44qh last accessed 31.01.2013

CSE 2011 – The smart metering programme: a consumer review http://tinyurl.com/o6tx9bp

last accessed 31.01.2013

BEUC 2011 – Empowering consumers through smart metering http://tinyurl.com/p6o4c7q

last accessed 16.05.2013

KEMA 2012 – Development of Best Practice Recommendations for Smart Meter Rollout in the Energy Community http://tinyurl.com/pcc8cdm last accessed 16.05.2013

Smart Regions 2012 – European Landscape Report 2012 http://tinyurl.com/ojhxege last accessed 11.02.2013

[IBV04] Reference introduced by

http://tinyurl.com/nkmhv7g

http://tinyurl.com/p9s2qht

http://tinyurl.com/pbh44qh

http://tinyurl.com/o6tx9bp

http://tinyurl.com/p6o4c7q

http://tinyurl.com/pcc8cdm

http://tinyurl.com/ojhxege

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EXECUTIVE SUMMARY

The analysis of the Smart Meter projects identified in the framework of WP1, “Collection”, is a necessary step to reach the goal of the Meter-ON Project, which is establishing guidelines for the implementation of smart metering solutions.

In this document, a topic-based analysis is performed by different task for each project. Each task addresses a specific set of information domains, which is shown in the following:

Technological Analysis: focuses on the different technologies involved in smart meters;

Quantitative Analysis: pays attention on the financing mechanisms, cost-benefits and

if the company adopted a make-or-buy approach;

Qualitative Analysis: focuses on regulatory & legal framework in place in each

country and in Europe;

Advanced Topics: investigates the possible applications of smart meters as a pillar of

smart grid functionalities.

Seven projects, which participated in the second data collection campaign, have been analyzed.

The analysis shows that, in most of the considered European countries, there is a plan for the development and implementation of smart metering systems. In some countries, these systems are already being rolled out or are in an advanced testing phase, while in one country these projects are in early stages, R&D or pilot, confirming the fact that these systems are universally recognized as one of the main blocks for the smart-grid development.

The greatest benefits that the smart-metering systems bring are a better observability and managing of the network that lead to an improvement of the overall efficiency, the reduction of technical and commercial losses, and the ability to integrate renewable energy resources and electric vehicles more easily. They also represent the means to implement further policies for demand response. So, smart-metering infrastructure bring benefit for customers, and overall society, and to system and DSO as well.

The results of the projects’ analyses are the main input for the WP3, “Lesson Learned and Recommendations”, which will incorporate cross-topic analyses (based on the information domains described above), reviews of the practices in the investigated projects and prescriptions to foster the positive evolution of smart metering taking into consideration current economic, social and technological trends in The European Union and the world.

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PURPOSE

The purpose of this deliverable is to provide an update of the topic-based analysis started in the deliverable D2.1. The analysis is performed for the projects identified in the second data collection campaign (see Deliverable D1.4). Each project has been individually analysed according to different information domains as identified in deliverable 1.1 “Stakeholder list, Advisory Board composition and Relevant information domains”, and consequently, for each information domain, a summary of the different approaches or characteristics is being provided (e.g., the most adopted solutions or the most common requirement).

1 Introduction

WP2 analyses each project and deployment initiative provided by WP1. A topic-based analysis is performed by different tasks, each addressing a particular set of information domains. Within WP2, each project is individually analysed concurrently by each task. The tasks identifying missing information highlight them to WP1 and require WP1 to provide access to them (whether is possible). Performing a topic-based analysis within different topic-related tasks ensures that the same information domain is addressed on each analysed project; furthermore, each task is performed by a given expert group being responsible to deepen the assigned information domain for each questioned smart-metering project.

2 OVERVIEW OF QUESTIONAIRE RESPONDING TO METER-ON

In order to gather information on past or ongoing smart metering projects in the framework of WP1, a data collection template has been elaborated and sent to all the project partners and affiliates to be filled in. The template addresses the most relevant topics on every considered smart meter project, including also contextual information, e.g. regarding regulatory framework, in force laws, information on the initiatives carried out to improve customer acceptance and ongoing smart grid developments.

The deliverable “Analysis of smart metering projects” relies on this questionnaire to perform a detailed assessment and interpretation of the information needed to outline the main features of each project and a summary of the main characteristics observed in the entire group of projects. The outcomes of the analysis will be considered in WP3 to draw a set of lessons learned on the basis of past experiences and recommendations for policymakers and utilities to foster the deployment of these technologies in Europe.

To accomplish the scope of the analysis, the work has been performed by taking into consideration 4 different tasks that correspond to the 4 domains of the template (besides general information about the demonstration projects):

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“Technology Analysis”, focuses the attention on the different technologies involved in smart meters. In particular, upstream and downstream communication technologies, used for the communication of the meters with possible data concentrators or data repeaters, as well as with the back-end system; local communication technologies (exploited by field workers for commissioning activities as well as by in-home devices for building automation or demand side management), and characteristics of the information collected, regarding type of data, collection frequency and configuration of parameters. In addition, cyber security and privacy analysis aims to highlight the adopted approaches to tackle the issues, in particular by outlining if authentication and encryption are foreseen in each smart metering project.

“Quantitative Analysis”, focuses the attention on the financing mechanisms, cost-benefits and if the company adopted a make-or-buy approach. Financing Mechanism Analysis aims at providing a rough cash-flow analysis for each analysed project, underlying the main economics of the projects like capital expenditures, operational expenditures, pay-back period, tariff-incoming, services-incoming, opportunity-costs, savings, return of the investment and internal rate of return. Make-or-buy and Development Process Analysis aims to underline which are the developing outsourcers, the equipment suppliers, the services suppliers and the contract manufacturers. When it is possible, it points out the financing mechanisms, the contracts the joint ventures and, whether is possible, the economical drivers (e.g., opportunity costs).

“Qualitative Analysis” focuses the attention on regulatory & legal framework in place in each country and in Europe to outline the framework conditions and their impact on the development of each smart metering project. Therefore, for each country remuneration scheme like Regulatory Asset Based and measurement services remuneration are considered to outline what regulators allow and require. The legal framework is also analysed to identify which legal entity is entitled and responsible for installing smart meters, operating them and providing metrological data and services. The Security of Electricity Supply Directive (2005/89/EC) addressed Smart Metering for the first time. Article 3 says that Member States shall take appropriate measures to safeguard the balance between the demand for electricity and availability of generation capacity, which may include. For each country it is shown how their regulatory and legal framework is influencing the adoption of real-time demand management technologies such as advanced metering systems, research and any other different approach taken by the authorities across the EU. User Acceptance and Customer Involvement is also assessed for each project, detailing how final customers have been involved, the initiatives taken from each company to foster the active participation of the users, and whether possible customer empowering devices like home displays or active demand systems were accepted or rejected by final customers.

“Advanced Topics” focuses on the possible applications of smart meters as a pillar to implement smart grid functionalities. This task underlines how the smart meter and

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Automated Metering Infrastructures impact on distribution network operation (network planning, operation and maintenance, technical and non-technical losses and quality of supply). It is also analyzed how they can be used to foster the penetration of Distributed Energy Resources and electric vehicle charging infrastructure, devices for empowering customers in demand response actions like in-home display showing metrological data and devices interacting with home appliances, for a fine-grained power quality analysis, metering of generation and, finally multi-metering, i.e., systems collecting metrological information for different utilities exploiting all possible synergies.

Overview of the technology analysis

From the analysis of the 7 projects participating in the second data collection campaign (see Deliverable D1.4) the following considerations emerge for the technology analysis.

Status

- 3 projects are being rolled out. In one case, there is a total involvement of the DSO customer base, while in another case it is planned to reach 90% of customers by 2020. The third project involves only 10% of customers so, in this case it is considered a “small roll-out” project.

- 3 projects are in the pilot phase. One involves 6300 customers (2.527.000 in case of

roll-out), one 2500 customers while the third involves 460 customers.

- 1 project is in R&D phase with a target of 400.000 customers involved by 2020.

Communication

- 5 projects use both PLC and GPRS technologies; one project uses PLC only, while

the last one uses GPRS technology only.

- The most used communication protocols are DLMS and IP-based which are used in 2

projects each respectively. Considering the remaining 3 projects, two use both DLMS

(PLC) and TCP-IP (GPRS/LAN), one project uses a proprietary protocol.

Local interfaces

- Out of the 7 projects considered, 4 of them present smart meters with an optical

interface. In one project there is also a serial RS-485 interface that implements the

Modbus protocol used for interfacing with the HAN. In the project in which there is no

optical interface both a numerical local interface and a tariff contact are present.

Display

- All projects but one have a smart meter with an alphanumerical display. In 3 cases it

is compatible with OBject Identification System (OBIS) codes. In the project in which

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the display is not alphanumeric, it presents predefined indicators and value fields.

Also, in one case there is the possibility to add an external display connected with a

wireless communication.

Electrically protective device and switchgear

- In 3 cases the smart meter has an electrical protective device, which is an overcurrent/short-circuit protection.

- In only 3 cases there is an internal switchgear, that is a circuit breaker that can be locally rearmed after a previous enabling.

- In one case there is a mechanism that can disconnect the customer due to power and/or energy limit exceeding, but it can’t be considered a fully-fledged circuit breaker.

Load control

- 5 projects make load control mechanisms available in the smart meter. In four cases it is simply based on the disconnection of the customer’s performed by the smart meter’s internal switchgear while in the remaining case it is based on the disconnection of the heating devices. In two cases there is a current/power limiter.

Backup power supply

- In 6 out of 7 projects the smart meter has a backup power supply. In 3 cases it is a supercap, in two cases it is a battery and in the last one it can be a battery or a supercap. In one project there is no backup power supply.

Remote clock synchronization

- In all projects the real-time clock of the smart meter is remotely synchronized. However, in one project it can be synchronized only for industrial customers.

Prepayment mechanism

- In 2 projects out of 7 there is a prepayment mechanism. In one project prepayment is an option for the future, while in the 4 remaining projects there are no prepayment mechanisms.

Contract management

- In three projects there is the possibility to manage contracts both locally and remotely. In other three projects this possibility is available only remotely while in one project there is no possibility to manage contracts.

Fraud detection

- In all projects there is a meter’s cover-open detection mechanism. In four projects there is also a magnetic field detector.

Cyber security

- In one project cyber security is still a work in progress. - All the remaining 6 projects ensure cyber security. Generally, it is done by the use of

the cyber security mechanisms defined in the communication protocol used. In some

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projects those mechanisms have been improved, for example by the insertion of further user’s access rights, by the use of a better authentication mechanism or by permitting the transmission of meter’s data only after a specific request by the concentrator.

- Data encryption is present in 6 projects.

Overview of the quantitative analysis

From the analysis of the further 7 projects participating in the second data collection campaign (see Deliverable D1.4), the following considerations emerge for the quantitative analysis.

Financial Information

In the financial information section, the picture is pretty dispersed. The value of the budget changes a lot, strongly depending on the kind of project under consideration (from pilot projects to roll-out). The highest budget sums up to 135M€ corresponding to 6300 meters. In three out of four available cases the funding type is 100% public (Eandis, Enexis BV and Fortum) while 12% funding type is public if considering EVN. The payback period is pretty much heterogeneous ranging from 9,7 and more than 50 years. The estimates of IRR are missing in all cases but for Eandis (6,84) and EDF (13), they are higher than the WACC, leading always to positive NPVs. Little information has been provided to analyze the Discount Rate.

Cost – Benefit

In this section, an overview of costs and forward looking benefits of projects M€ (million euros) vs. operative or M€/year (million euros per year) is provided. Considering capital costs, it may be noticed that there is a remarkable variance; e.g. considering Fortum (87,50%), Liander (98,87%) or EVN (48,28%) respectively. Considering field devices cost, data appear to be pretty heterogeneous; only three cases are available: Eandis (10,87%), EDF (0,19%) and Fortum (12,5%). Little information is also available on data communication infrastructure: Eandis (9,47%), EDF (0,20%) and Fortum (51,76%). With reference to operative costs – using the same taxonomy – costs allocation significantly changes; in facts in premise costs lies around 67% of the operative costs in two out of three available cases; in only two projects, data on field devices costs (EDF 0,18% and EVN 59%,) and on data communication infrastructure (EDF 70,14% and Fortum 33%) are available

Estimated benefits are scattered according to the beneficiary: (i) consumer, (ii) industry, (ii) country and (iv) others. Moreover, expected benefits are calculated using the same metrics; M€ or M€/year consistently with costs. It is a well-known fact that the estimation of benefits across time is complex and requires complete information. If one focuses on consumer M€ benefits, available data from the two available cases show 76% as an average while

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business benefits’ share approximately 41,5%; other beneficiaries do not cover a notable role. Taking into consideration the M€/year benefits, consumer benefits are approximately 54% (three cases available); about 44% is the share of business benefits.

Finally, the cost section is contains two tables, we in fact distinguished costs in M€ and M€/year.

Supply Chain

The picture remains pretty dispersed, as in the first group of projects. Again, at an aggregated level, while the level of integration ranges from “null or very low integration” (as an example, the case of GNF – Spain) to “extreme” integration (a couple of examples: Enel Muntenia, and ERDF – France), some activities are on the average performed internally, like Logistics, Maintenance, and Data Management; on the other hand, Manufacturing is always performed by suppliers. When it comes to suppliers belonging to the group, the supply is almost always performed by a single supplier (except the case of EANDIS – Belgium), showing a somehow close relationship; as for the suppliers not belonging to the group, there is a mixture of single/multiple supplier and Long/Short-Term Buyer-Supplier-Relationship (BSR) in place (please notice that the majority of the BSRs are Long-Term ones). Not enough information is provided to discuss the most relevant costs for the current Supply Chains.

As for the prospective (or current) roll-out projects, a few differences can be highlighted. The structure of the SC should not vary, apart from a few cases. In one case (EDP – Portugal), Data Communication (currently performed only by suppliers) will be also performed internally; in addition, there are some clues about the future BSRs, including multiple suppliers and both Long and Short-Term relationships. In a second case (Enel – Romania), the level of integration will decrease dramatically, up to only performing internally the Logistics and Data Communication activities; Manufacturing, Installation, and Maintenance will be bought from multiple suppliers, by means of Long-Term BSRs. In a third case (ENEXIS – Netherlands), the level of integration will decrease from “complete” to extreme, outsourcing the manufacturing activity. Minor changes/refinements can also be observed in the cases of ERDF – France, where Tendering will be the only way to deal with suppliers (whilst currently LT and ST BSRs co-exist), and GNF – Spain, where information is provided about BSRs (multiple suppliers, LT BSRs).

Overview of the qualitative analysis

From the analysis of the further 7 projects participating in the second data collection campaign (see Deliverable D1.4) the following considerations emerge for the qualitative analysis.

The “Third Energy Package” aims at creating a more competitive and transparent European Energy Market that will benefit end-users by gradually integrating national markets, making supplies more secure and strengthening European Union’s competitiveness. According to Directive 2009/72/EC, European energy networks are subject to unbundling requirements

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which oblige all Member States to make certain that vertically integrated energy companies are separated into various stages of energy supply: generation, distribution, transmission and supply. The deadline for transposing the 3rd Energy Package into national legislation has been set for 03.03.2011, but as practice shows each Member State has various interpretations of the matter as shown in the below analysis. Information regarding the current status has been collected through the project’s questionnaire and also analysing the available literature on the matter (accessed until October 2013). The preference of regulatory and legal instruments to promote smart metering ranges from mandating its introduction through the definition of minimum technical requirements and adding, or not, some financial incentives to the other extreme of removing regulatory and legal barriers, thus enabling, and not mandating, smarting metering. As for the customer’s side the analysis points out the acceptance and involvement issues in the running/finished projects. The involvement of the customer is noted to be a complex point linked to the regulation in place in each Member State, where customers are expected to be engaged in these changes, but as some evidence show the information needs to be shared in a more accessible and understandable manner for them not to see smart meters as a danger or privacy intruder and to experience real benefits from their usage, thus ensuring that utilities companies offer the best value for energy and related services. It is observed that in some cases companies running the smart metering projects adopts a clear strategy targeting the engagement of the end-users, but in other cases it is clear how the focus is more on the technological side and how the customer is not involved at the early stage of implementation. The initiatives to engage the consumers in the smart metering implementation range from basic informative letters on the matter with updates throughout the process, to round-table meetings with the stakeholders and to large-scale surveys and Customer Service platforms to attract customers in providing their opinions and to enhance their interaction with the smart meter.

Overview of the advanced topics

From the analysis of the further 7 projects participating in the second data collection campaign (see Deliverable D1.4) the following considerations emerge for the advanced topic analysis.

Impact of smart metering on distribution network operation

One half of the DSOs have not provided information about the impact on distribution network operation.

Regarding network planning and maintenance, the other half has not executed any experiment yet, except of Fortum, who will integrate AMM meters with the Distribution Management System (DMS), receiving real-time alarms. Power quality and event data will be used for planning of maintenance investments.

The impact on technical losses is positive for Hungary and Finland; however, the non-technical losses are only considered for Hungary, because they are already small, and smart

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metering makes them even smaller. The other projects have not provided any information on this topic.

Regarding the information on quality of service, just EDF Demasz has provided information about the improvement on this topic due to smart meters, for example voltage quality or network outages data.

EV Charging Infrastructure

The smart metering allows the deployment of EV charging infrastructures able to manage the charges and minimize the impact of EV penetration in the power grid, maintaining the conditions of QoS and continuity of the supply. Smart meters also enable the possibility of EVs to support the power system, giving remaining energy to the grid in case of need systemically (Vehicle to Grid, V2G), or locally (Vehicle to Home, V2H).

Smart metering systems from Enexis, Liander and Fortum deal with innovative services for EV charging, and, in the case of Enexis, also for V2G, while EDF Démasz pilot and EVN AG do not provide EV charging services.

Distributed Generation

In order to facilitate the introduction of distributed generators, smart meters implement the ability of measuring information about the generation patterns. On this matter, for EDF Démasz and Fortum, the meter is programmed to get incremental values from the six magnitudes, A+, A- and reactive energy in 4 quadrants. Smart meter can take bi-directional measures, reactive energy measures, apart from the compliance with standard AMI functions. Enexis is responsible for metering data collected from domestic end customers/prosumers. However, EVN AG meters are not able to measure produced energy. No information is provided by the rest of DSOs.

Demand Response

All DSOs but two include Demand Response activities in their projects. Several of them (EDF Démasz, Enexis, Liander and Fortum) provide different interfaces to consult the smart meter information, such as web interface, TV, smartphone, in-home display, and EVN AG provides just a display. In addition, EDF Démasz and Fortum provide Time of Use tariffs.

In Hungary and the Netherlands, no initiatives are carried out from the National Regulatory Authorities. In Finland, demand response is a basic and accepted service. Fortum meters have a load control relay, used to control loads at customer sites.

Two DSOs (EDF Démasz and Liander) are going to perform market tests to evaluate the potential impact on the customer acceptance of such initiatives

Regarding the participation in pilot projects, Enexis is involved in different initiatives, such as Zuby, Plugwise, and pilots in Breda/Zwolle, while Fortum is conducting the Dynamic Load control pilot, where meter relay is used to control heating load to be on during cheapest spot price hours.

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Other services

Regarding other advanced metering solutions, half of the DSOs are involved in developing multimetering solutions. On this matter, EDF Démasz is developing a multi-solution project, where gas and water meters will be installed, without an existing electricity smart metering infrastructure. Dutch smart metering systems (Enexis and Liander) are for electricity and gas (water and heat meters are owned by other companies). EVN AG smart metering system also combines electricity and gas meters.

3 CASE STUDIES

3.1 Austria

Regulatory framework and market overview

National Regulation on smart meter

The Electricity Act (EIWOG1) passed by the Austrian Parliament in November 2010 contains regulation which takes into consideration the 3rd Energy Package of the EU (2009/72/EC2). Related to smart metering the law delegates the responsible ministry (Ministry of Economy, Family and Youth) to conduct a CBA on which to consult the regulator (E-Control), organisations for consumer protection and the Austrian Data Protection Commission and this should be followed by a decree introducing a mass rollout of smart meters.

E-Control has published in 2010 (republished 20113) a catalogue with the minimum requirements for smart metering and a CBA4 on this issue (2010). The CBA performed by the Austrian NRA rendered, in all four depicted scenarios, that positive overall effects can be achieved with certain prerequisites among which: the implementation needs to be fully coordinated through all the sectors involved, consistent and open standards for metering technologies and data formats, the introduction of electricity smart meters needs to be done before the gas smart meters in order to avoid duplicated infrastructures, the interfaces for energy consumption of

1 EIWOG - Elektrizitätswirtschafts- und organisationsgesetz - http://www.e-

control.at/portal/page/portal/medienbibliothek/strom/dokumente/pdfs/ElWOG%202010_en.pdf 2 Directive 2009/72/EC http://eur-

lex.europa.eu/LexUriServ/LexUriServ.do?uri=OJ:L:2009:211:0055:0093:EN:PDF 3 E-Control Requirements for Smart Meters 2011 http://www.e-

control.at/portal/page/portal/medienbibliothek/gas/dokumente/pdfs/IMA-VO_en.pdf 4 Cost-benefit analysis on smart metering in Austria http://www.e-

control.at/portal/page/portal/medienbibliothek/strom/dokumente/pdfs/pwc-austria-smart-metering-e-control-06-2010.pdf

http://www.e-control.at/portal/page/portal/medienbibliothek/strom/dokumente/pdfs/ElWOG%202010_en.pdf

http://www.e-control.at/portal/page/portal/medienbibliothek/strom/dokumente/pdfs/ElWOG%202010_en.pdf

http://eur-lex.europa.eu/LexUriServ/LexUriServ.do?uri=OJ:L:2009:211:0055:0093:EN:PDF


http://www.e-control.at/portal/page/portal/medienbibliothek/gas/dokumente/pdfs/IMA-VO_en.pdf

http://www.e-control.at/portal/page/portal/medienbibliothek/gas/dokumente/pdfs/IMA-VO_en.pdf

http://www.e-control.at/portal/page/portal/medienbibliothek/strom/dokumente/pdfs/pwc-austria-smart-metering-e-control-06-2010.pdf



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and for customers need to be customizable and comprehensible (web portals and at least monthly consumption information available)

The Ministry of Economy, Family and Youth has issued a decree in April 2012 calling for the roll-out of smart meters for 95% of all end consumers by 20195. According to this decree DSOs are obliged to report to the Ministry on the progress of smart meters installed, the incurred costs, experiences with privacy, consumer behaviour on electricity consumption. E-Control’s task is to continuously monitor the national smart meter implementation progress and to provide annual reports (topics to be covered: summarized DSOs results, trends in energy pricing, energy efficiency developments).

So far legal ownership unbundling (ITO) has been the preferred unbundling method, leaving DSOs with a limited control over the power grids, which they rent from a vertically integrated producer and/or supplier.

In Austria TSOs, apart from operating transmission grids, also act as control area managers (CAM), in this role they are responsible for the physical balancing of electricity generation and demand. At the end of 2010 there were three TSOs regulating three control areas in Austria: “Voralberg” (VKW Netz AG), “Tirol” (TIWAG Netz AG) and “East Austria” (APG AG). APG AG is the main Austrian electricity TSO, owning approximately 94% of the Austrian high-voltage electricity grid and operating it as well6. As of 2012 APG AG has been assigned as the CAM for the whole of Austria, thus enabling a cost-effective implementation of EU’s guidelines for grid operators.

Distributors and customers shares for each distributor At distribution level in the electricity sector there are 130 DSOs7 for 5,5 million meters8 .

Distributors replying to the questionnaire 2 Austrian DSOs have replied: EVN and Stromnetz Steiermark

3.1.1 EVN

The EVN smart meter project is a pilot test started in 2008 and finished in 2012. It has involved 300 customers plus other 160 customers in another pilot test project. The 94% of the entire customers are residential.

5 Introduction of smart meters in Austria – Regulation

http://www.bmwfj.gv.at/Ministerium/Rechtsvorschriften/kundgemachte_rechtsvorschriften/Documents/Intelligente%20Messger%C3%A4te.pdf 6 European Commission, Energy Markets in the European Union 2011

http://ec.europa.eu/energy/gas_electricity/doc/20121217_energy_market_2011_lr_en.pdf 7 http://ec.europa.eu/energy/gas_electricity/doc/20121217_energy_market_2011_lr_en.pdf

8 http://futurezone.at/netzpolitik/smart-meter-zwang-in-oesterreich-faellt/24.598.389

http://www.bmwfj.gv.at/Ministerium/Rechtsvorschriften/kundgemachte_rechtsvorschriften/Documents/Intelligente%20Messger%C3%A4te.pdf

http://www.bmwfj.gv.at/Ministerium/Rechtsvorschriften/kundgemachte_rechtsvorschriften/Documents/Intelligente%20Messger%C3%A4te.pdf

http://ec.europa.eu/energy/gas_electricity/doc/20121217_energy_market_2011_lr_en.pdf

http://ec.europa.eu/energy/gas_electricity/doc/20121217_energy_market_2011_lr_en.pdf

http://futurezone.at/netzpolitik/smart-meter-zwang-in-oesterreich-faellt/24.598.389

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Overview of the Power Grid

Yearly energy distributed (TWh)

The customers are spread around in different parts of the

distribution grid. A detailed assignment is not possible.

Types of residential meters installed

Both single and polyphase

Average residential yearly consumption (KWh)

3500 kWh

3.1.1.1 Technological analysis of the solution deployed

EVN: AMI Architecture After identifying the participants for this pilot project the Landis+Gyr meters have been installed. Equipped with a GPRS modem the electricity meter is directly connected to the Meter-Data-Management (aim from Landis+Gyr) via an IP connection. The Meter-Data-Management Warehouse supports the billing solution (SAP Utilities IS-U) and the web-portal OEMS. The electricity meter is equipped with another modem (868 MHz radio) to communicate with the in-home display (eco meter) and the gas smart meter (if installed at the same customer premise). The electricity meter acts as data concentrator for the gas and electricity meter data.

EVN: Main Features of Electricity Smart Meters (single and three phases)

Only three phase meters are present in the project. The meter has a short circuit protection device tuned on 30xImax and a react time less than 10ms and has a supercap as backup power supply. The meter has an alphanumerical display and also has the possibility to add an external display (in-home display). There are no billing profiles for residential customers, while for industrial ones there is a monthly billing profile. There is no possibility to control the load and to remotely manage a load reduction. The meter has a fraud detection mechanism that detects unauthorized cover open.

THREE PHASE

Meter average life 8 years

Presence of internal switchgear No

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List of international standard that meter is compliant to

IEC 62053-21

IEC 62053-23

EN 50470-3

IEC 60529 IP 52

IEC 61000-4-2

IEC 61000-4-3

IEC 61000-4-4

IEC 61000-4-5

IEC 62052-11

EVN: Main Features of Electricity Smart Meters

THREE PHASE

Frequency for reading Residential: yearly; industry: monthly

Active energy measurement Only imported active energy is measured

Reactive energy measurement No

Number of annual tariff programs that can be programmed 0

Number of weekly tariff programs that can be programmed for each annual program

0

Number of daily tariff programs that can be programmed for each weekly tariff programs

0

Number of daily tariff intervals that can be programmed 0

Possibility to remotely manage supply contracts No

Possibility to locally manage supply contracts No

Load control support No

Event log recording No

Record of information about power outages and quality of supply

Only power losses in industries

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Presence of demand management feature implemented No

Presence prepayment management implemented No

Local interfaces Not available

Possibility to remotely download firmware No

3.1.1.2 Economic analysis of the solution deployed

Costs & Benefits

Cost Category Detailed Cost Actor

Incurring Cost

%

In premise cost

Meters (€) DSO 19,1%

Installation of Meters (€) DSO 25,4%

In Home Displays (if applicable) Energy

supplier 3,8%

Subtotal 48,28%

Data communication infrastructure

Capex (€) DSO 46,38%

Opex (€) DSO 5,34%

Subtotal 51,72%

Total 100%

Scope of the analysis is to simplify data regarding main costs and benefits.. Considering the structure of the questionnaire’s section dedicated to costs and benefits, we aim at resuming results using a classification of costs and benefits consistently with their nature; M€/year or M€.. The mentioned macro categories, yearly (M€/year) and unit of money (M€), are mostly allocable to opex and capex; however some exceptions may occur. In premise cost covers 48,28% of total (M€), this share is lower the average of all presented cases which is nearly 80%. Among in premise cost, as data contained in the table show, the installation of meters cover a remarkable role. The remaining is the share of data communication infrastructure whilst neither field devices costs nor other costs are included.

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Incurring Cost

%

In premise cost Operation and maintenance of meters (€/year) DSO -

Field devices costs Operation and maintenance of data collectors (€/year) DSO 59,01%

Other Costs

Energy consumed by smart metering assets (€/year) DSO -

Pavement reading inefficiency (€/year annual average) DSO 3,28%

Marketing (€/year annual average) DSO 34,42%

Legal costs (€/year annual average) DSO 2,20%

Organizational costs (e.g. data protection, ongoing regulation, assurance, accreditation, tendering) (€/year annual average)

DSO 1,10%

Total 100%

Provided that detailed values are available in the corresponding table, one may note that in premise cost is missing, and that field devices costs (59,01%), are by far the most significant. Other costs are important too; in fact, yearly marketing expenses are expected to reach 34,42% out of 41% of all in other costs.

Assessment of benefits and identification of beneficiaries require forward-looking statements. In this descriptive summary we classify benefits according to beneficiary’s category and, consistently, with the costs section, M€/year against M€. In this case, all benefits (described as energy savings (100%) fall into the category “consumer benefits”. No yearly benefits data are available.

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Benefit Category Detailed Benefit Beneficiary %

Consumer Benefits

Energy Savings (€) (Calculated for 2 500 customers) Consumer 63,6%

Energy Savings (gross annual reduction in demand, %) Consumer 36,4%

Subtotal 100%

Business Benefits

Deferred generation capacity investments (€) Other 0%

Deferred transmission capacity investments (€) Other 0%

Deferred distribution capacity investments (€) DSO 0%

Subtotal 0%

Total 100%


Business Benefits

Reduction of meter reading and operations cost (reading, billing, customer care) (€/year)

DSO 0%

Reduction of operations and maintenance cost (assets and equipment breakdowns) (€/year)

DSO 0%

Reduction in electricity technical losses (€/year) DSO 0%

Reduction in commercial losses (thefts, frauds, …) (€/year) DSO 0%

Reduction in outage times (thefts, frauds, …) (€/year) DSO 0%

Total -

Supply Chain

SC of the Project in Progress:

SC MACRO TIER RESPONDENT SUPPLIERS BELONGING

TO THE GROUP OTHER SUPPLIERS

Manufacturing 2; also supplying

competitors; LT BSR

Logistics X

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Installation X

Maintenance X

Data Comm. 1; also supplying

competitors; ST BSR

Data Management X

The project in progress is being deployed by means of a relevant Supply Chain (SC) vertical integration. Among the 6 main necessary macro-tiers (Manufacturing and assembly, Logistics, Installation, Maintenance, Data Communication, Data Management), 4 out of 6 (Logistics, Installation, Maintenance, Data Management) are performed internally. Manufacturing and assembly is performed by 2 suppliers not belonging to the group also supplying competitors, with long-term Buyer-Supplier-Relationship. Data Communication is performed by a single supplier not belonging to the group also supplying competitors, with short-term Buyer-Supplier-Relationship. As far as it concerns the costs related to each macro-tier for the current project (basing on the available data), the most relevant ones for the initial investment are Manufacturing and Assembling and Logistics (50% out of the total cost per unit) and Installation and Maintenance (50% out of the total cost per unit). Data Communication is considerably expensive, considering the duration of the project. Data Management is accounted a lump sum.

3.1.1.3 Customer involvement

For their pilot project, EVN has used the classic informative letters and attaching the respective contracts. Also a survey has been distributed and focus group meetings were arranged. The focus of the survey was on the usage of home displays, which seemed to increase the interest of residential consumers as it provides the best way to visualize their consumption. The topics that need improvement are monthly billing and the web portal which seem to be far below the customers’ expectations. As for adapting Customers Services there is no plan at the moment on behalf of EVN, but they are considering that in case of a roll out they will need more capacity in field engineers and call center agents. According to EVN the NRA has not monitored the customers’ satisfaction regarding smart metering. Current status of installation and use of smart metering The EVN AG smart meter project started in 2008 and ended in 2012. It consist in 300 electricity meters (plus 160 additional PLC meters in another pilot test project) and 30 gas meters. It involves 460 customers, of which 93.75% are residential, that correspond at 0.04% of the total customer of EVN AG.

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Vulnerable customer focus It has not been considered in this case as this was a small pilot project. Opt out focus According to EVN four-fifths customers wanted to opt out, so one fifth accepted the smart meter. The customers which did not wanted to have a smart meter installed were left with analog meters.

3.1.1.4 Other advanced solutions enabled by smart meters

Impact on distribution network operation No information provided Core of the EV charging infrastructure EVN AG smart metering system does not deal with any innovative service for EV charging. Support of Distributed Generation Smart metering is not applicable to measure produced energy. Capacity of enabling Demand Response Regarding advanced features related to demand response, an in-home display is provided. It has signals (red, yellow, green) to show the actual range of consumed power. This information helps to avoid switching consuming applications on at the same time. EVN AG has not developed innovative solutions which leverage on smart metering infrastructure to promote energy efficiency, active participation of end consumers or demand response. The interfaces used to get access to the meter data are web interface, monthly bills and in-home displays. EVN AG has not conducted market tests to evaluate the potential impact of the solutions on the consumer awareness/customer acceptance. They are not also involved in any ongoing demand project. Other advanced metering solutions

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EVN AG smart metering system combines electricity and gas meters for some customers. The gas smart meter is connected via 868 MHz radio to the electricity smart meter as data concentrator, and the data is forwarded to the Meter-Data-Management. Based on the metering infrastructure model, suppliers are responsible of meter manufacturing (Landis+Gyr) and communication device manufacturing (e.g. concentrators), while the DSO is responsible for meter installation and maintenance, communication device installation and maintenance, central system management, meter reading and data management. The deadlines for the gas meters roll out are the same as for electricity meters: 15 % until 2015, 45 % until 2017, 95 % until 2019. In opposition to the National Regulatory Authority (NRA) study, another one from the Austrian advocacy group for the electricity industry finds a worse result: the costs are being higher than the ones calculated by the NRA (E-Control in Austria), and, in the end, a negative result for the benefit is obtained. This study can be forwarded, as it is not available on the website of www.oesterreichsenergie.at. The required functionalities established by NRA for the electricity meter includes the interface to four other non-electricity meters, performing the multi-metering option.

In-home display is included, as a value added service.

3.1.2 Stromnetz

The Stromnetz smart meter project is currently in its R&D phase. It started in 2009 and in 2012 it finished the planning phase. At the beginning of the 2013 the project started the pilot test with 500 household involved. It is planned to start a mass testing in 2014, and involving 400.000 customers by the 2020. Energie Steiermark is about to finish its planning phase at the middle of 2013. It can be stated that Energie Steiermark will act as supplier and service provider, Stromnetz Steiermark as a distribution system operator.


Yearly energy distributed (TWh) 7,9

Number of HV/MV substations; 74

Number of MV/LV substations; 6920

Average residential contractual power (KW) 4 kW

http://www.oesterreichsenergie.at/

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Stromnetz: AMI Architecture The architecture of the Advanced Metering Infrastructure is based on Data Concentrator which is installed in the low voltage side of the secondary substation. It uses a PLC connection between concentrator and smart meter or a GSM connection for hardly readable meters. The target protocol is IPv6. Data are retrieved by the meter once a day during normal operation, and consist of 2 energy registers from 100 % of meters and 2 channels of 15min load profiles from about 25 % of meters. Stromnetz: Main Features of Electricity Smart Meters (single and three phases) Single phase and three phase meter share the same communication technology. Smart Meter self-consumption is about 2 W in case of non-active communication for the single-phase one and 6W for three-phase. The meter has no protective device but has an internal breaker that can be rearmed both locally and remotely. The maximum cut-off current is 100 A both for single phase and three phase meters. The meters have a supercap as backup power supply. The meter presents an alphanumerical display compatible with OBIS code and showing information through the use of one or two buttons. A 15 minutes load profile is available. There is only a single annual, weekly and daily tariff program that can be programmed. It also offer the possibility to control the load through by remotely disconnect the internal breaker.

SINGLE PHASE THREE PHASE

Meter average life 13

Presence of internal switchgear

Internal breaker. Can be remotely disconnected and reconnected.

It can be also locally reconnected.

Max cut-off current is 100A

Internal breaker. Can be remotely disconnected and reconnected.

It can be also locally reconnected.

Max cut-off current is 100A


CEN/CLC/ETSI/TR 50572 (M/441)

Stromnetz: Main Functions of Electricity Smart Meters (single and three phases) Single phase and three phase meter has identical main functionalities.

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Frequency for reading Daily

Active energy measurement Bi-directional

Reactive energy measurement No

Number of annual tariff programs that can be programmed

1


1


1

Number of daily tariff intervals that can be programmed

1

Possibility to remotely manage supply contracts

Yes


Load control support Yes, by remotely disconnecting the internal breaker

Event log recording Yes


Yes

Demand management feature implemented No

Prepayment management implemented Not within the meter, only disconnection an re-connection managed by MDM

Local interfaces

Local service interface (optical)

Local customer interface

Interface for gas and water meters (MBus)

Possibility to remotely download firmware Yes


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Costs & Benefits

No available data.

Supply Chain

No available data.


Smart Home Pilot has just been launched in Austria but no detailed information in terms of ownership, installation and management of the smart meter solution and meter data cannot be provided according to the questionnaire respondent. Current status of installation and use of smart metering The Energie Steiermark smart meter project has started in 2009 and it is expected to finish deployment in 2020. The planning phase has finished in 2012 and at the moment the pilot test has just started, involving about 500 households. It is foreseen that in 2020 there will be 400.000 meters installed, that correspond to 99% of the total customers of Energie Steiermark. Vulnerable customer focus No information available. Opt out focus No information available.


Impact on distribution network operation No information provided Core of the EV charging infrastructure No information provided Support of Distributed Generation No information provided Capacity of enabling Demand Response No information provided Other advanced metering solutions

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No information provided

Conclusions on Austria The Austrian regulator (E-Control) has published in 2010 (republished in 2011) a catalogue with the minimum requirements for smart metering and a CBA. The CBA performed by the Austrian NRA rendered, in all four depicted scenarios, that positive overall effects can be achieved. The Ministry of Economy, Family and Youth has issued a decree in April 2012 calling for the roll-out of smart meters for 95% of all end consumers by 2019. So far legal ownership unbundling (ITO) has been the preferred unbundling method, leaving DSOs with a limited control over the power grids, which they rent from a vertically integrated producer and/or supplier. In Austria TSOs, apart from operating transmission grids, also act as control area managers (CAM), in this role they are responsible for the physical balancing of electricity generation and demand. In Austria, at distribution level in the electricity sector, there are 130 DSOs for 5,5 million meters. Two of them have replied to the questionnaire: EVN and Stromnetz Steiermark. In both cases the projects are in the initial stage, and some information is missing. The communication technology used to communicate with smart meters varies among DSOs, but the most common one uses both PLC and GPRS with an IPv4 protocol. The budgets for the projects are financed with both private and publics funds. Customer involvement is usually done by an informative letter and a web portal. There is not enough information regarding advanced topic. In one case seems that the DSO is not interested on them (no demand response strategy, no DER or EV integration) although it is interested in multimetering solution, integrating GAS smart meter that communicate via zigbee with the electricity smart meter.

3.2 Belgium


National Regulation on smart meter

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Belgium has a federal structure with one federal government and three regional governments. This situation has been transposed also in the energy matters, as these four governments have different levels of competence on the topic. Due to this division of responsibilities all the EU directives need to be implemented on both the federal and regional levels. The regional governments of Flanders, Wallonia and Brussels-Capital have implemented the DSO unbundling provisions as per the 3rd Energy Package in their respective legislation. Even if there is no legislation on smart metering, the topic is high on the agenda of all stakeholders. The three regions have their own regulator and implicitly independent business cases. There is no CBA for the whole Belgium but regional regulators (VREG9 , CWaPE10 and Brugel11 ) have conducted various studies in their respective jurisdiction. In Flanders (80% of the market is designated to one DSO – EANDIS CVBA) there is positive business case with a net present value of 144 million EUR. This business case uses the communication technologies as proposed by the distribution grid operators. The major cost item is the investment in smart meters. Other important costs are the investments in data management and communications and project roll-out costs. The main (declared) benefits are the benefits coming from saving energy through monthly feedback on energy consumption, savings on physical meter readings and the savings by reducing non-billable usage. As this positive outcome emerged, the regulator VREG has listed the possible minimum functionalities12 which are largely consistent with the ones recommended by the EU. In Wallonia there is a negative business case with a net present value of -186 million EUR in the roll out scenario. In Brussels-Capital there is a negative business case with a net present value of -170 million EUR in the roll-out scenario. The sum of these three business cases could be interpreted as the national cost benefit. But if this is done, it must taken into account that the three business cases have been performed by different parties with a different approach. The focus in Belgium is on technical tests of the meters and the communication technology. Several pilot projects are in progress or being prepared (Sibelga with 200

9 CBA for Flanders http://www.vreg.be/sites/default/files/uploads/kema.pdf (NL)

10 CBA for Wallonia http://www.cwape.be/docs/?doc=688 (FR)

11 CBA for Brussels http://www.brugel.be/Files/media/AVIS/AVIS136_SmartMetering_20120420_33622_1.pdf (FR)

12 Functionaliteiten van slimme meters http://www.vreg.be/rapp-2011-12 (NL)

http://www.vreg.be/sites/default/files/uploads/kema.pdf

http://www.cwape.be/docs/?doc=688

http://www.brugel.be/Files/media/AVIS/AVIS136_SmartMetering_20120420_33622_1.pdf

http://www.vreg.be/rapp-2011-12

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electricity meters, Eandis with 4,000 meters in the cities of Leest and Hombeek, some 40,000 meters by 2012 and a plan for a complete rollout of 2.5 million electricity and 1.5 million gas meters by 2019).

Distributors and customers shares for each distributor Belgium has a total of 26 DSOs split amongst its regions: 1 DSO operating in

Brussels Region 1 DSO, 13 DSOs in Wallonia, and 12 DSOs in Flanders.

Distributors replying to the questionnaire For this country analysis one DSO have replied: Eandis.

3.2.1 EANDIS

The Eandis smart meter project, started in 2007, has been carried out with two actions. A Proof of Concept, as R&D phase, where 4.300 meters has been installed and a Pilot phase, to be completed by the end of 2013, with the objective of installing 40000 meters (2000 before the end of 2012). At the moment a project end date has still not been arranged.


Yearly energy distributed (TWh) 0,033 TWh

HV,MV and LV voltage levels 30-70 kV / 1-30 kV / < 1kV

Number of HV/MV substations; n.a.


Average residential contractual power (KW) n.a.

Average residential yearly consumption (KWh) 5200 kWh


Eandis: AMI Architecture The architecture of the Advanced Metering Infrastructure is based on a multi gateway approach and it works with any PLC modulation scheme. It does not exclude the use of Orthogonal Frequency-Division Multiplexing OFDM although the increase in network quality, thanks to filtering, is such that a simple narrowband PLC modulation

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scheme, like Spread-Frequency Shift Keying S-FSK (proof of concept project) or Phase-shift keying PSK (pilot project), is largely sufficient. The Smart Communication Module, when directly connected to a broadband connection, can handle 24 smart meters during normal operating conditions (read-out every 15 minutes). On the other side, when directly connected to a PLC connection, the Smart Communication Module can handle 4 smart meters during normal operating conditions (read-out every 15 minutes). The available communication interfaces on data collector are the following: a Power Line Communication (PLC), Ethernet interface (home area network (HAN), wide area network (WAN) and the Local Area Network (LAN)), M-Bus interface, RS 485 interface and optionally GPRS or WiFi by adding a hardware component in the expansion slot. The used communication protocol is Device Language Message Specification (DLMS) over TCP-IP Ethernet between the meter and the smart communication module. Clock of data collector can be remotely synchronized and is managed through UTC. Alarms are sent by a smart communication module that pushes them on a periodical basis towards the AMM. The hardware of the data collector is identical for both phase-to-phase and phase-to-neutral systems solution and the concentrator has a consumption of 5W on average, but system is still under development. The adopted communication solution allows 99,9% of reading success rate of load profile acquisition and the reason for unsuccessful readings are purely ICT related. PLC is the most susceptible of all communication solutions, mainly because the equipment installed and used by the customer is not predictable. For this reason PLC filters have been installed in order to isolate the noise and impedance interference caused by various consumer equipments. On average the electricity meter load profiles have 2 channels consisting of 10 entries and every single entry is a few bytes on average.

Eandis: Main Features of Electricity Smart Meters (single and three phases) Single phase and three phase meter share the same communication technology. Smart Meter self-consumption is the same both in case of active and non-active communication because the communication is outside of the meter itself: less than 2W in voltage circuit and less than 4 VA in current circuits. The meter has no protective device but has an internal breaker that can be rearmed both locally and remotely. The maximum cut-off current is 100A both for single phase and three phase meters. The meters has an on board battery as backup power supply. The meter presents an LCD display with custom icons and numeric fields.


Meter average life 15 years

Presence of internal Yes, switchgear is in place: breaker. Rearmament (reconnection) is

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switchgear possible by pushing an accessible button when meter is in “ready to connect” status. If rearmament is done remotely, the status has to be set from a central side system. If load limitation was the cause, the rearmament will be set immediately.


EN 50470-1

EN 50470-3

EN 62052-11

EN 62053-21

EN 62053-23

EN 62053-31

DIN 43856

DIN 43857

EN 60529

EN 60947-1

EN 60947-3

Eandis: Main Functions of Electricity Smart Meters (single and three phases) Single phase and three phase meter has identical main functionalities.


Frequency for reading Every 15 minutes

Active energy measurement Yes

Reactive energy measurement Yes


4 season profiles


4 week profiles


8 daily profiles

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8 daily profiles


Yes

Possibility to locally manage supply contracts

Yes (technician on site required)

Load control support

Yes, load limitation function is available. Tripping curve: one measurement quantity threshold and one time threshold can be configured. Customer can reconnect immediately by pushing a button

The meter record events in an event log

List of monitored parameters

Yes, multiple event logs. Standard event log: grid events, fraud events, and disconnection events.


Yes

Demand management feature implemented

Yes, used for switching heating equipment (a special tariff regime exists in Belgium for heating purposes)

Prepayment management implemented

The meters can show 8 prepayment registers, which are set by the central system. Calculations are done in the central system. Access to these registers is possible via pin code in order to guarantee privacy.

Local interfaces

Meter: optical interface for local access for field operations, rs 485 or Ethernet connection to additional communication module. A P1 HAN interface is foreseen through the separate communication module.

Possibility to remotely download firmware

Yes, except for metrological firmware


Costs & Benefits


Incurring Cost

%

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In premise cost



Communications equipment in premise (if applicable; e.g. WAN communication module) (€)

DSO 21,16%

In Home Displays (if applicable) DSO -

Subtotal 65,84%

Field devices costs

Data collectors (€) DSO 13,17%

Installation of data collectors (€) n.a. -

Subtotal 13,17%



Opex (€) DSO 0,19%

Subtotal 11,47%

Other Costs

Disposal (€) DSO 0,12%

Stranding costs (costs incurred when a meter is taken out of service before the end of its expected economic life) (€)

DSO -

Subtotal 0,12%

Other Costs (optional)

Fraud detection and follow up DSO 9,53%

Subtotal 9,53%

Total 100%

As the above table shows, in premise cost covers a remarkable share (65,84%) of total costs, this share is roughtly 14% below the average share of other considered cases taken into consideration which, instead, is nearly 80%. Anyway, in analyzing data at an aggregate level, it can be noticed that there is high variance. The percentage of field devices costs is 13,17%, whilst data communication infrastructure represents 11,74%, other costs (included optional) amount to 9,53%; primarily because of costs related to fraud detection and follow up.


Incurring Cost

%

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In premise cost Operation and maintenance of meters (€/year) DSO 67,14%

Field devices costs Operation and maintenance of data collectors (€/year) DSO -

Other Costs

Energy consumed by smart metering assets (€/year) DSO 27,56%

Pavement reading inefficiency (€/year annual average) DSO -

Marketing (€/year annual average) Other 5,30%

Legal costs (€/year annual average) DSO -


DSO -

Total 100%

In premise cost, specifically the operation and maintenance of meters covers approximately two-thirds of the total. Field device costs and data communication infrastructure costs are missing while other costs (largely energy consumed by smart metering assets) correspond to 32,86% of the total.

In this descriptive summary we classify benefits according to beneficiary’s category and, consistently with the costs section. Consumers benefits add up to 57,61% of the total yearly benefits; whilst business benefits reach 42,39%. No country-wide data are available.

Lastly, the results indicate that business benefits equal 44,89%, country-wide benefits 7,12% and other benefits cover 47,99% of total M€. Considering other costs, one may note that 29,41% fall into allocation and balancing, 6,19% regard call center activities while 12,38% are described as “switching”.

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Consumer Benefits

Energy Savings (€/year) (Calculated for 2 500 customers) Consumer 35,66%

Energy Savings (gross annual reduction in demand, % per year)

Consumer -

Peak load transfer (€/year) Consumer 21,95%

Subtotal 57,61%

Business Benefits


DSO 31,82%


DSO 5,49%

Reduction in electricity technical losses (€/year) n.a. 0,15%

Reduction in commercial losses (thefts, frauds, …) (€/year) DSO 4,94%

Reduction in outage times (thefts, frauds, …) (€/year) n.a. -

Subtotal 42,39%

Total 100%

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Business Benefits

Deferred generation capacity investments (€) Other 1,55%

Deferred transmission capacity investments (€) Other 12,38%

Deferred distribution capacity investments (€) DSO 30,96%

Subtotal 44,89%

Country-wide benefits

Global CO2 reduction (Ton CO2 and € if applicable) Other 7,12%

EU Emission Trading Scheme from energy reduction (€) (if applicable)

Other -

EU Emission Trading Scheme from application of Time Of Use tariffs (€) (if applicable)

Other -

Subtotal 7,12%

Other Benefits

Allocation and balancing DSO 29,41%

Call center DSO 6,19%

Switching DSO 12,38%

Subtotal 47,99%

Total 100%

Supply Chain


SC MACRO TIER

RESPONDENT SUPPLIERS BELONGING



competitors; LT BSR

Logistics X

Installation X >1; not supplying

competitors

Maintenance X

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Data Comm. 2

Data Management

X

The project in progress is being deployed by means of a low Supply Chain (SC) vertical integration. Among the 6 main necessary macro-tiers (Manufacturing and assembly, Logistics, Installation, Maintenance, Data Communication, Data Management), 1 out of 6 (Maintenance) is performed completely internally, and 1 out of 6 (Installation) is performed both internally and by other companies belonging to the group. As for the other macro-tiers, the majority (3 out of 6: Manufacturing, Logistics, Data Communication) of the players are external suppliers, whilst the remaining ones (2 out of 6: Installation, Data Management) are companies belonging to the group. EANDIS buys from multiple suppliers (not supplying competitors) when belonging to the group (for the Installation; no information about Data Management), and buys from multiple (for Manufacturing and assembly, Data Communication) (also supplying competitors in the case of Manufacturing) suppliers with long-term (LT) Buyer-Supplier Relationships (BSR) currently in place (in the case of Manufacturing and assembly) when companies do not belong to the group; no information about Logistics, also performed from external suppliers. As far as it concerns the costs related to each macro-tier within the project in progress, no information is provided.

SC of the Roll-out:




competitors; LT BSR

Logistics X

Installation X

>1; not supplying

competitors

Maintenance X

Data Comm. 2

Data Management X

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The SC for the future roll-out is expected to be the same as the one in progress. As far as it concerns the costs related to each macro-tier for the future roll-out (basing on the available data), the most relevant ones as for the initial investment are Manufacturing and Assembling (68% out of the total cost per unit), and Installation (32% out of the total cost per unit). Data Communication is considerably expensive considering the duration of the project. Maintenance (1% of the total cost) and Data Management are negligible.


The responder of the questionnaire did not answer this part. However from the publicly available information it is observed that Eandis has had already various initiatives related to their smart metering projects in Flanders. From April 2010 – February 2012 the company ran a survey among its customers having a central question in place: How much impact do smart meters have in terms of saving energy13 ? For this question to be answered they established three reference groups of customers:

Customers with a smart meter who received a consumption report and documentation on rational use of energy (RUE).

Customers with a conventional meter who did not receive a consumption report but who did receive RUE documentation.

Customers with a remote-reading meter who did not receive a consumption report or RUE documentation.

Some 20% of people, which participated to the survey, showed active interest in saving energy, while 80% of people in Flanders admitted to not having any interest. The first conclusions indicate that smart meters (which allows to produce reports with detailed breakdowns of consumption) have a significant impact on energy savings when it comes to electricity. On the other hand, smart meters did not have any significant effect on gas consumption. Households with a smart meter saved more electricity than those with a conventional meter who only received RUE documentation. The difference in savings between these two groups of the test population amounted to 4.5%. Translated into terms of the Flemish population (taking into account the weighting of the respective customer segments) the saving amounted to 2.6%. From the survey it also emerged that positive feedback had a big influence on energy-efficient behaviour. Further, households that make savings can be found among all customer segments, including those who initially were not interested. Thus the largest potential savings for smart meters are still to come, namely among the 80% of the population who currently are only passively interested in saving energy.

13

From smart meter to smart user - http://www.eandis.be/eandis/pdf/21120E3.DOC_DataId_8789831_Version_1.pdf

http://www.eandis.be/eandis/pdf/21120E3.DOC_DataId_8789831_Version_1.pdf

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Current status of installation and use of smart metering The Eandis CVBA smart meter project has started in 2007 and the project end data has to be announced. In case of rollout, it is foreseen that 2.527.000 meters will be installed. Vulnerable customer focus No information provided. Opt out focus The customer can choose that the installed smart meter does not communicate more than necessary to comply with current market processes. The network user may choose to refrain from an automatic remote reading. There is an exception for remote meter reading for the annual meter reading, when moving or changing supplier. The customer can notify the utility (opt out) during installation or at a later time by letter or by telephone.


Impact on distribution network operation No information provided Core of the EV charging infrastructure No information provided Support of Distributed Generation No information provided Capacity of enabling Demand Response No information provided Other advanced metering solutions The Belgian NRA has evaluated a cost benefit analysis for smart metering. The information is public and available at http://www.vreg.be/sites/default/files/uploads/kema.pdf (Dutch only). This analysis clarifies that a partial rollout of only profitable segments does not lead to a positive social business case. With significant investments at the beginning of the rollout, there are also significant benefits that require a full rollout to materialize. Additionally, the cost of the used communication technologies significantly increases. Finally, it can be concluded that extending the deployment of a large part of the connections, over a long

http://www.vreg.be/sites/default/files/uploads/kema.pdf

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period of time can be risky and, in most cases, it will lead to a deterioration of the social business case.

Conclusions on Belgium

In Belgium, even if there is no legislation on smart metering, the topic is high on the agenda of all stakeholders.

The focus is on technical tests of the meters and the communication technology. For this reason a lot of pilot projects are in progress or being prepared.

Belgium has a total of 26 DSOs split amongst its regions: 1 DSO in the Brussels Region 1 DSO, 13 DSOs in Wallonia, and 12 DSOs Flanders, but for this country analysis only one DSO have replied to the questionnaire: Eandis.

The total budget for the project covers R&D and test projects, and it’s funded entirely by public funding through electricity distribution rates.

The communication path between meters and concentrator is based on a multi-gateway approach, so each meter has multiply options to connect and upload its data. The gateway is the Smart Communication Module and uses both PLC and LAN communication technology with DMLS or TCP-IP protocol to communicate with meters.

Eandis has had already various initiatives related to their smart metering projects in Flanders. Particularly, the company ran a survey among its customers, having, as central question, the impact of smart meters in terms of energy saving.

No information was provided regarding other advanced solutions enabled by smart meters.

3.3 Finland


National Regulation on smart meter The Electricity Market Act (66/2009) stipulated that Finland should have 80% smart meter coverage by 2014, but the real penetration is close to 100% at the moment, as DSOs have been active in leveraging the benefits of smarts meters to their customers. In this decree 66/2009 also the minimum functionalities have been set and in general they cover EU’s recommendations such as: delivering hourly data once a day to the customer, a standardized connection for monitoring real-time electricity consumption, as well as demands for load control capabilities.

Finnish Power Grid Plc (Fingrid), which was founded in August 1997, is responsible for high-voltage power transmission on the national grid. In addition to the grid

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comprising the 400 kV, 220 kV and 110 kV power lines, the company owns also cross-border lines between Finland and Sweden, Finland and Norway and Finland and Russia. Fingrid’s owners are Fortum Plc and Pohjolan Voima Oy, each of which owns about one fourth of the shares of the company, the State of Finland with about one eighth of the shares, as well as some institutional investors. Fingrid forms a central part of the Finnish power system. The Electricity Market Act lays down strict requirements for the fairness and impartiality of the company’s operations. The 110 kV transmission lines not included in the grid form regional networks or have been closely connected to distribution networks. About 10 such networks are operated by one regional distribution company and 60 other companies14.

Distributors and customers shares for each distributor Regional electricity companies are responsible for electricity distribution on distribution networks (networks below 110 kV). There are 91 such companies in Finland today. Along with the sale of electricity utilities, their number has decreased drastically from the original 200 companies in the past 20 years. The majority of the companies are in municipal ownership. Traditionally electricity utilities have been operated as municipal corporations or public enterprises.15

Distributors replying to the questionnaire For this country analysis one DSO has replied: Fortum Sahkonsiirto Oy.

3.3.1 Fortum Sahkonsiirto Oy

The Fortum smart meter project has started on November 2007 and it’s expected to finish on March 2014. It’s a rollout that involves about 583.000 customers, 98% of which are residential. The regulatory deadline to complete installation was the end of 2013 and at the end of 2012 it was at a stage of completion around 75%. Rollout covers Fortum Sähkönsiirto Oy and Fortum Espoo Distribution Oy grid areas. The sourcing model is Service Provider model, where the Service Provider supplies the meters, installs them, operates and maintains them and provides ongoing services (e.g. meter reading services). Service Provider is Telvent (part of Schneider Electric group), meters are supplied by Echelon and installations are done by Eltel Networks Oy.

14

http://www.energiamarkkinavirasto.fi/data.asp?articleid=231&pgid=127 15

Idem14

http://www.energiamarkkinavirasto.fi/data.asp?articleid=231&pgid=127

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HV,MV and LV voltage levels 110 kV, 20 kV, 0,4 kV



Types of residential meters installed Both single and polyphase

Average residential yearly consumption (KWh) 8500 kWh


Fortum: AMI Architecture The central system is called Titanium, an integral platform to deploy and manage an Advanced Metering Infrastructure (AMI) and its related services. Titanium runs on top of NES. Echelon’s Networked Energy Services (NES) system is a highly scalable and adaptable smart metering system that includes a network of intelligent energy management devices, gateways that collect data from the devices, and NES System Software that provides the tools to manage devices and gateways. Titanium automates all infrastructure processes by making use of the APIs exposed by NES. Supported devices include utility meters (including Control Point Modules - CPMs), M-Bus devices, and MEP devices. Supported gateways include the Data Concentrators and Edge Control Nodes (ECNs). An IP-based wide area network (WAN) provides the connection between the Data Concentrators in the field and the Titanium/NES System Software in the back office. These components work together to provide the core infrastructure for delivering smart metering services. Current configuration is dimensioned to manage up to 1 million meters, but the system is fully scalable and proven to handle 10 million meters. Downstream communications to Data Concentrators are 3G/GPRS, connection to data concentrators is done via secure VPN network through a M2M virtual operator. The NES system automatically synchronizes the time across the system based on the time source used for the servers. All Servers hosting the Titanium/NES solution are synchronized to the same Time Server via NTP protocol. NES System Software checks and updates the time on the Data Concentrator each time a connection is made (with the exception of the Server Initiated High Priority connections). The Data Concentrator checks and adjusts the time on meters once per day, using the Meter Time Synchronization function that runs when the Data Concentrator first reboots (or shortly thereafter). The function is scheduled to run at 12:00 (UTC) each day after that. Data Concentrator power consumption is tipically 5-10W. Data collector is fully interoperable with phase to phase and phase to neutral systems.

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Fortum: Main Features of Electricity Smart Meters (single and three phases) Single phase and three phase meter share the same communication technology. The meters have a typical power consumption of 1,4 W (with an absolute maximum of 2,5 W) in case of active communication. On the other side when communication is not active the apparent power is less than 5VA. The trip point of the load disconnection for excessive power use is programmable and is based on a maximum active power value threshold and time duration configurable by the utility. This feature can be enabled or disabled. The load disconnect contactor does not have thermal overload or over-current protection. External fuses or a circuit breaker must be provided to protect the premises wiring system. The load disconnect contactor is not intended to be used as a substitute for a circuit breaker. The maximum switching current is 100A and the maximum overload current is 120A. A battery in the meter provides power to maintain clock accuracy and allows for cover removal tamper detection during a power outage. The battery cannot be removed or replaced. The meter is equipped with an alphanumeric display. The meter offers various types of demand calculations that can be performed to measure the peak active and reactive power being delivered to the system over a designated time period. The electrical values that are provided by the meter include meter energy, instantaneous values such as voltage and current, and pulse inputs. All values are updated once per second for usage such as viewing, data logging, or communications. The meter load profile data log can be configured to record up to 16 different energy values at once. The load profile log is divided into groups of data called blocks. It is possible to specify the duration of each block by setting the number of intervals per block, as well as the length of each interval. Up to 16 channels can be recorded on the same interval. The 16 channels are selected from the measured electrical values. Four annual tariffs with 10 possible time assignment per day can be programmed.


Meter average life At least 20 years


The load disconnect contactor in the meter provides a manual means of load disconnect, automatic prepay control, automatic trip at programmed power levels, and remote disconnect operation. The load disconnect contactor can be electronically turned off as a result of several configurable conditions. It can be turned on manually using the disconnect switch push buttons. It can also be turned on remotely with NES System Software, or directly via the optical port using the Provisioning Tool. Note that the abilityto turn on the load disconnect contactor remotely can be disabled. The load disconnect contactor is not intended to be used as a substitute for a circuit breaker.

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Maximum switching current: 100A Maximum overload current: 120A, 150A (30 min.) Maximum switching voltage: 277 VAC Short circuit <3mS: 3,000A Maximum switching power: 27kVA


IEC 62052-11 IEC 62053-21 IEC 62053-23 IEC 62052-21 IEC 62054-21

IEC 61010-1

EN 50065-1 EN 50470-3 DIN 43857 DIN 43864

ANSII C12.18

ANSI C12.19

IEC 62053-31

IEC 62056-21

DIN EN 13757-2

DIN EN 13757-3

Fortum: Main Functions of Electricity Smart Meters (single and three phases)

Single phase and three phase meter have identical main functionalities.


Frequency for reading Data logging intervals: User-selected at 5, 10, 15, 20, 30, 60 minutes, or 1 day

Active energy measurement

Bi-directional

Reactive energy measurement

Detected in 4 quadrants


4 tariffs with 10 possible time assignments per day. 4-seasons per perpetual calendar (set by Day/Month). Perpetual holiday calendar for up to 15 holidays / year. Perpetual daylight savings changeover. 2 separate holiday day schedules per season. 1 weekday, 1 Saturday,

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and 1 Sunday day schedule per season.

4 Time-of-Use tariff implemented.

There may be different day schedules for weekdays, Saturday, Sunday, and holidays.


See above


See above


See above


Yes


Yes


Yes, one optional control relay can operate an external low current device, such as a contactor coil, which in turn can control a larger amperage device. The open or closed state of the control relay is determined by the present tariff level that is in effect. The tariff period that activates the relay is configurable. The relay can also be set into the open or closed state remotely by NES System Software or locally with the Provisioning Tool.



How information can be accessed

The event log records the occurrence of meter events and fault conditions that are selected to be logged. The date and time of each event occurrence is included in the log. Some events include numeric codes to provide more detail about the event, such as the specific type of action that occurred, a table or procedure number, or the new season or tariff that took effect. The event log shows a zero (0) when no code value is available for that event, or if one of the available codes is zero and that is the valid indication. The event log stores up to 100 of the most recent events. When the event log is full, the oldest events are over-written. NES System Software supports event logging on the meter by allowing customers to configure (options are either Enable or Disable) which events result in an entry in the meter’s event log and allowing customers to read the meter’s event log configuration. Continuous event logging allows new event log

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entries from devices to flow into NES System Software automatically without requiring an explicit command to read the entire event log. Then using events in an NES system, you can either receive events as they occur via SOAP, or periodically poll for events on a scheduled basis.


The meter monitors various parameters for power quality. Power quality events can be read by the Data Concentrator and transmitted to NES System Software, and can also be read directly from the meter via the optical port. The meter provides power quality measurements for the following: Voltage (RMS) sag (under voltage), Voltage (RMS) swell (over voltage), Over-current (RMS), Power outages, Frequency, Phase loss, Total harmonic distortion (THD)


Customers might want to use the load control relay for demand management purposes, but it is driven from the central system, not at the meter level.

Prepayment management implemented

Any meter can be remotely converted to a prepay meter with NES System Software. Other remote commands allow the loading of normal and emergency credits into meters, changing the rate that credits are consumed, and reading the remaining number of credits in a meter. In addition, prepay meters generate events that are delivered by NES System Software when credits are depleted, and when the prepay buzzer has been reset by the customer. The meter will automatically turn off the load disconnect contactor once the credit level in energy (not currency) has gone to zero in a prepay metering installation. The meter reduces the amount of remaining credit based on energy usage and tariff level.

Local interfaces

An optical port (IEC 61107 Optical Probe With USB Connector) is provided for local communications at 9600 Baud. The optional M-Bus capabilities in the Echelon IEC electric meters can discover and query up to four M-Bus devices, such as gas, water, or heat meters. The collected data and status messages of the Echelon meters are sent to the utility central service center through the NES network. The Echelon meter can perform the functionality of an M-Bus mini-master, meeting standards EN13757-2: 2002 and EN13757-3: 2002. The meter supports the baud rates of 300, 2400, and 9600 for communication to connected M-Bus devices. The meter optionally provides a new bidirectional, isolated UART serial port that is called a MEP port. The MEP port allows a connected smart device to access meter data, run meter procedures, and have limited write access to the meter.


Yes

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Costs & Benefits


Incurring Cost

%

In premise cost




- -

In Home Displays (if applicable) - -

Subtotal 87,50%

Field devices costs


Installation of data collectors (€) DSO 4,17%

Subtotal 12,50%


Capex (€) - -

Subtotal -

Other Costs

Disposal (€) - -


- -

Subtotal -

Total 100,00%

The purpose of this description is to simplify data regarding main costs and benefits coming from the questionnaire. Considering the structure of the questionnaire’s section dedicated to costs and benefits, we aim at resuming results using a classification of costs and benefits consistently with their nature; M€/year or M€ without changing totals, in an effort to provide unbiased information. The mentioned macro categories, yearly (M€/year) and unit of money (M€), are mostly allocable to opex and capex; however some exceptions may occur. In premise cost covers 87,50% of total costs (M€), this share is almost 8% more than the average of all presented cases which is nearly 80%. Differently from other projects, we note that the subcategories of in premise cost, namely meters and Installation of Meters resemble

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in terms of importance. The percentage of field devices costs is 12,5% while information on data communication infrastructure and other costs is not available.


Incurring Cost

%


Field devices costs Operation and maintenance of data collectors (€/year) - -


Opex (€/year) DSO 33,33%

Other Costs

Energy consumed by smart metering assets (€/year) - -

Pavement reading inefficiency (€/year annual average) - -

Marketing (€/year annual average) - -

Legal costs (€/year annual average) - -


- -

Total 100%

Provided that detailed values are available in the corresponding table, one may note that data in premise cost covers around 66,67% of M€/year whilst data communication infrastructure 33,331%, no data are available for other costs cost and field device costs.

Assessment of benefits and identification of beneficiaries require forward-looking statements. In this descriptive summary we classify benefits according to beneficiary’s category and, consistently with the costs section, M€/year against M€. Considering the total of yearly benefits; consumers accounts for 28% and business add up to 8%; a remarkable share is covered by other benefits (64%) described as regulatory income (meter investments are included to regulated asset base i.e. the investment can be charged from grid customers like other grid investments) occur.


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Business Benefits

Deferred generation capacity investments (€) - -

Deferred transmission capacity investments (€) - -

Deferred distribution capacity investments (€) - -


Global CO2 reduction (Ton CO2 and € if applicable) - -


- -


- -

Subtotal -

Total -

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Consumer Benefits

Energy Savings (€/year) (Calculated for 2 500 customers) Consumer 28,00%


Consumer -

Peak load transfer (€/year) Consumer -

Subtotal 28,00%

Business Benefits


DSO -


DSO 7,00%

Reduction in electricity technical losses (€/year) - -


Reduction in outage times (thefts, frauds, …) (€/year) - -

Subtotal 8,00%

Other benefits Regulatory income (meter investments are included to regulated asset base i.e. the investment can be charged from grid customers like other grid investments)

DSO 64,00%

Subtotal 64,00%

Total 100%

Supply Chain


SC MACRO TIER RESPONDENT SUPPLIERS

BELONGING TO THE GROUP

OTHER SUPPLIERS


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competitors; LT BSR

Logistics 1; also supplying

competitors; ST BSR

Installation 2; not supplying

competitors; LT BSR

Maintenance 1; not supplying

competitors; LT BSR


competitors; LT BSR

Data Management 1; also supplying

competitors; LT BSR

The project in progress is being deployed by means of no Supply Chain (SC) vertical integration. Among the 6 main necessary macro-tiers (Manufacturing and assembly, Logistics, Installation, Maintenance, Data Communication, Data Management), none is performed internally, whilst all of them are performed by suppliers not belonging to the group. In 2 out of 6 cases (Maintenance, Data Communication), suppliers are not supplying also competitors. In one single case (Logistics), short-term BSR are set with the supplier. As far as it concerns the costs related to each macro-tier within the project in progress, no information is provided.

SC of the Roll-out:

SC MACRO TIER RESPONDENT SUPPLIERS

BELONGING TO THE GROUP

OTHER SUPPLIERS

Manufacturing 1; not supplying

competitors; LT BSR

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Logistics 1; also supplying

competitors; LT BSR

Installation 2; also supplying

competitors; LT BSR

Maintenance 1; not supplying

competitors; LT BSR


competitors; LT BSR

Data Management 1; also supplying

competitors; LT BSR

The SC for the future roll-out is expected similar to the one in progress, except from the fact that the Manufacturing supplier will not supply competitors, the BSR for Logistics will be long-term ones, and the Installation supplier will also supply competitors. As far as it concerns the costs related to each macro-tier within the roll-out, no information is provided.


Fortum has tailored an integrated and detailed communication campaign in order to inform their customers of the meter changes. According to Fortum the Finnish NRA has not performed a systematic follow-up regarding customer’s satisfaction/acceptance on the smart metering service. Current status of installation and use of smart metering The Fortum Sähkönsiirto Oy smart meter project has started in 2007 and it is expected to finish deployment in 2014. At current time it involves about 583.000 customers, 98% of which are residential. By the end of 2013, all Finnish households will have a smart meter installed16. Vulnerable customer focus

16

Fortum – Smart metering status: http://www.fortum.com/en/sustainability/topical-themes/solar-economy-web/smart%20metering/pages/default.aspx

http://www.fortum.com/en/sustainability/topical-themes/solar-economy-web/smart%20metering/pages/default.aspx

http://www.fortum.com/en/sustainability/topical-themes/solar-economy-web/smart%20metering/pages/default.aspx

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For electro sensitive customers17 a special process has been designed. It has been found that PLC based solution are more acceptable for electro sensitive customers than P2P. Opt out focus Fortum has experienced very low opt-out rates: from 583000 changed meters only 100 customers wished not change their metering option, thus continuing with manual readings.


Impact on distribution network operation

AMM meters will be integrated with Distribution Management System (DMS). Certain defined alarms are delivered real-time to DMS, and DMS can query the status of specific meters.

Regarding network planning, power quality and event data, as well as data on technical losses, will be used for planning of maintenance investments, i.e. maintenance investments will be focused on grid areas with high frequency of quality problems.

Non technical losses are already small in Finland, and smart metering makes them even smaller, so they are not considered an important issue. Technical losses can be accurately measured after deployment of smart meters, and they will be used as an input to grid maintenance.

Core of the EV charging infrastructure

FORTUM deals with smart charging for EV at high level plans only, based in ZigBee and C-band.

Support of Distributed Generation FORTUM meters use four-quadrant measurement. Supply to grid causes a meter event, which is separately collected. Local production supply to grid is managed under separate contract with the prosumer, i.e., consumption and supply are separated. Capacity of enabling Demand Response

As an advanced feature for demand response, FORTUM meters have one load control relay, used to control loads at customer sites. This relay replaces ripple control system. Demand

17

EHS(electro hypersensitivity) is defined by the World Health Organization as: “…a phenomenon where individuals experience adverse health effects while in the vicinity of devices emanating electric, magnetic, or electromagnetic fields.” http://www.weepinitiative.org/talkingtoyourdoctor.pdf

http://www.weepinitiative.org/talkingtoyourdoctor.pdf

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response is associated with day/night tariff scheme. About ¼ of grid customers in Finland have some load under utility control, usually heating load (water boiler). Utility controlled load has been the standard installation in single house dwellings since 1970's in Finland, and today there are more than 500 MW of load under utility control.

In order to promote energy efficiency and demand response, regulation requires daily delivery of hourly meter readings to consumers, which are delivered in a custom built internet application. Under development are also ZigBee / C-band based in-home display service.

The interfaces used to access the meter data are Internet service and in-home display (under development).

Utility controlled demand response is a basic and accepted service in Finland; e.g., in FORTUM grid area, there are 160 000 of 600 000 customers under DSO controlled Time Based Load Control scheme, linked typically to day / night tariffs and load control activated by DSO when the night tariff (cheaper) time begins.

The demand response activities in which FORTUM is involved includes the Dynamic Load Control pilot, where meter relay is used to control heating load to be on during cheapest spot price hours. This service makes sense for the customer if they have hourly priced electricity product.

The electricity market regulation in Finland requires all Utilities to provide Day/Night tariff (ToU) and Seasonal tariff (high price in winter, low price otherwise). Other advanced metering solutions FORTUM is not developing other advanced metering solutions, such as heat, water, or gas metering; they are separated businesses.

Conclusions on Finland The Electricity Market Act (66/2009) stipulated that Finland should have 80% smart meter coverage by 2014, but the real penetration is close to 100% at the moment, as DSOs have been active in leveraging the benefits of smarts meters to their customers. In this decree 66/2009 also the minimum functionalities have been set and in general they cover EU’s recommendations.

Regional electricity companies are responsible for electricity distribution on distribution networks (networks below 110 kV). There are 91 companies in Finland today. One of them has replied to the questionnaire: Fortum Sahkonsiirto Oy.

The total budget for the project is financed entirely by public funding.

Communication from central system to data concentrators is IP-based via 3G/GPRS technology, while communication from data concentrator to meters are based on power line carrier (PLC) using Echelon’s A-Band PLC technology.

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Fortum has tailored an integrated and detailed communication campaign in order to inform their customers on the meter changes.

The main benefits of the smart metering infrastructures regard a better monitoring of the grid, with the aim of improve the quality of the service, and the operability of the grid itself, and to get better scheduled maintenance and the upgrading of the grid. With regard to advanced topic, Fortum has already integrated the managing of distributed energy resources and a way to manage the demand response. Fortum doesn’t seem to be interested in multi-metering solutions.

3.4 Hungary


National Regulation on smart meter Even if in Hungary there is no legislation regarding the introduction of smart meters, the country has taken certain steps in ensuring alignment with the current EU directives. All DSOs were legally unbundled based on the provisions of Directives 2003/54/EC and 2009/72/EC. The commercial and technical quality standards set by the NRA - Magyar Energia Hivatal - MEH (Hungarian Energy Office – HEO). Hungary’s electricity Law18 has some references with regards to the smart metering implementation. The main articles referring to this:

The Law empowers the government to take measures which explicitly set standards and requirements concerning smart metering;

The Law allows that distribution companies (both in electricity and gas sector) may perform smart metering projects. The consent applies to project companies also which are (will be) founded specifically for smart metering experiment;

The Law authorizes the companies to use store and handle the personal data of customers and payers.

As for the electricity tariff schemes those are not developed yet. They will be edited, created and offered by the supplier (USP) and the AMI operator will support their implementation.. In the study commissioned by the HEO in 2010 regarding the cost benefit analysis19 different scenarios for the smart metering implementation were assessed and the

18

Act LXXXVI of 2007 - http://www.mekh.hu/en/data-of-public-interest/legislation/electricity.html 19

Assessment of smart metering models: the case of Hungary - http://www.esmap.org/sites/esmap.org/files/P110874_Hungary_Assessment%20of%20Smart%20Metering%20Models_Dobozi.pdf

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recommendation is to implement a system with legally separated but regulated meter operators and for the rollout for domestic customers to be launched in 2014. It is compulsory to carry out the installation of meters and AMI systems and make an evaluation and summary report about all kind of experiences by the end of 2013. The nationwide program is coordinated by the HEO. At the moment only pilot projects are available as there is no national electricity smart metering implementation (rollout), nor any data about the status of other distribution companies. The responsible for meter installation, meter maintenance, meter reading and meter data management is the distribution company based on territorial principle. The distribution company owns the meters and measurement data too.

Distributors and customers shares for each distributor In Hungary there are 6 distribution companies and one TSO (MAVIR Zrt): 3 owned by E.ON (44%); 2 by RWE (44%); 1 by EdF(12%)20.

Distributors replying to the questionnaire For this country analysis one DSO has replied: EDF Demasz

3.4.1 EDF Demasz

The EDF Demasz smart meter project has started on February 2012 and it has finished on December 2013. It’s a pilot that involves about 2500 residential customers. The expected meters to be installed are 3300 (2800 with GPRS communication module and 530 meters with PLC communication); the difference between meters and customers derive from the fact that in Hungary customers may choose the so called tariff “B”. Technically it means a separate meter installed (switched and controlled by the DSO with a RCR, ripple control receiver). The synergy project is part of a nationwide smart metering program, which is coordinated by the regulator (Hungarian Energy Office) and all the DSOs take part in it.

20

DSO market shares slide 22- http://tinyurl.com/qjtfd2s

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Yearly energy distributed (TWh) 3,98 (in 2011)

HV,MV and LV voltage levels HV: 120 kV, MV: 22 and 11

kV; LV: 0,4 kV




Average residential yearly consumption (KWh) 1337


EDF Demasz: AMI Architecture The main components of the AMI system applied in the smart metering pilot project are the following: smart meters provided by three different meter vendors (ISKRAEMECO, ZPA and SAGEMCOM), an Head End software named SEP2W (Iskraemeco product), which controls and supervises all the meter activity, a data management and processing system performed by the platform Energy IP (eMeter product), an application named ESB (Enterprise Service Bus) which transmits data from SEP2W to Energy IP, and an application, named Energy Engage which, via web, provides access and services for customers. The meters are equipped with GPRS or PLC communication modules. The applied concentrators type are P2LPC. (Iskraemeco) and XP3000 (Sagemcom), and the installation covers three secondary substation’s service area. The number of installed PLC meters is 530 while the communication from concentrator to the head end (SEP2W) is through GPRS network, using TCP/IP protocol. The time of the data collection system is set to UTC time daily while the time of meters is synchronized to the data collector. The sending mechanisms of the alarms to central system are both push and pull because they are different by meter types. The Iskraemeco and Sagemcom meters store data, and it’s possible to retrieve them by calling the meter only. On the other side the ZPA meters send the alarm messages automatically to a dedicated IP address after it has occurred. Data concentrators are operable with phase-to-neutral system only and have a self-consumption of 25W. EDF Demasz Main Features of Electricity Smart Meters (single and three phases) Single phase and three phase meter share the same communication technology, but one of the meter vendors, Sagemcom, make available just the single phase one. The meters have a typical PLC power consumption of less than 10 VA in case of active communication. On the other side, when communication is not active, the consumption is 2 W. Circuit breaker against short circuit and over current are installed

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in front of the meter which also includes two kinds of internal switchgear: a breaker devoted to interrupt the main line and a relay for auxiliary devices. The breaker reconnection by the user is possible if the meter is in state of ready to reconnect; that happens if a reconnection command has been previously received. The maximum switching current is 80A and a built in super cap in the meter provides power supply in two of the three meters (ZPA and Sagemcom), while a Li-ion battery is used in the other one (Iskraemeco). The meter presents an alphanumerical LCD display compatible with OBIS code which offers different operational mode, mainly automatic scrolling and push-button ones, but in the case of ZPA meter also a service mode is available. There are four season annual tariff program that can be programmed in association with 4 weekly programs and 4 types of day.


Meter average life The obligatory recalibration period in Hungary is 10 years. The real lifetime we estimate about 20 years.

Presence of internal switchgear Yes, both breaker and relay


EN50470-1

EN50470-3

IEC 62052-11

IEC 62053-21

IEC 62053-23

IEC 62052-21

EDF Demasz: Main Functions of Electricity Smart Meters (single and three phases)

Single phase and three phase meter have identical main functionalities.


Frequency for reading Daily

Active energy measurement

Bidirectional (values stored separately)

Reactive energy measurement

Just positive and negative reactive

Number of annual tariff 4 seasons

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programs that can be programmed


4 weekly program


4 types of day


4 for Iskraemeco and ZPA meters, 6 for Sagemcom meters


Yes


Yes


The meters support load control: power or current thresholds and delay of disconnection time can be set into each type of meter. The values are remotely manageable and the reconnection must always be performed by the customer.




Yes. The meters register 23 types of different events. The number of registered events can be maximum 64. The main events are: meter or terminal cover opening, events related to power or/and phase failures, events or load profile clear, strong magnetic field presence.


Yes, both

Presence of demand management feature implemented

Yes. Power limitation possibility

Presence prepayment management implemented

Not implemented in the present phase of the pilot, but is an option for future development. It requires the implementation of additional modules both to the CIS (Customer Information System) and

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Energy IP.

Local interfaces

Iskraemeco meters:

Optical port, terminals for wired MBus devices or dongle (for connection of gas and/or water sub meters), Relay for external devices (240V, 5A), two outputs (optomos relay, 230V AC-DC)

Sagemcom meters:

Optical port, terminals for wired MBus devices or dongle (for connection of gas and/or water sub meters), 2 inputs and 2 outputs for external devices.

ZPA meters:

Optical port, RS485 port.


Theoretically yes (not yet tested. According to the manufacturers, the functionality is enabled )


Costs & Benefits

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Incurring Cost

%

In premise cost




DSO -

In Home Displays (if applicable) n.a. -

Subtotal 79,86%

Field devices costs


Installation of data collectors (€) DSO 0,03%

Subtotal 0,19%



Subtotal 0,20%

Other Costs

Disposal (€) n.a. -


DSO 2,11%

Subtotal 2,11%

Other Costs (optional)

UCS (Unified Computer System) servers (€) Other 16,31%

Software licence fees (paid after 2013.12.31) (€) Other 1,34%

Subtotal 17,65%

Total 100%

We aim at resuming questionnaire’s results using a classification of costs and benefits consistently with their nature; €/year or €, in an effort to provide unbiased information. The mentioned macro categories, yearly (€/year) and unit of money (€), are mostly allocable to opex and capex; however some exceptions may occur. Considering this case, where values are expressed in € (not in M€), in premise cost is by far the biggest type covering 79,86% of total costs (€), this share equals the average of all presented cases which is roughly 80%. The percentage of field devices costs is 0,19%, whilst data communication infrastructure represents 0,2%, other costs amount (optional included) to 19,76%; a remarkable share considering the average of other cases.

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Incurring Cost

%


Field devices costs Operation and maintenance of data collectors (€/year) DSO 0,18%


Opex (€/year) DSO 70,14%

Other Costs

Energy consumed by smart metering assets (€/year) DSO 11,88%

Pavement reading inefficiency (€/year annual average) n.a.

Marketing (€/year annual average) DSO 14,07%

Legal costs (€/year annual average) n.a. -


n.a. -

Total 100%

Given that detailed values are available in the corresponding table, one may note that in premise cost are around 3,73% €/year, field device cost sum to 0,18%, data communication infrastructure 70,14% where other costs correspond to 25,95%.

Assessment of benefits and identification of beneficiaries require forward-looking statements. In this descriptive summary we classify benefits according to beneficiary’s category and, consistently with the costs section, €/year against €. Looking at the total yearly benefits, consumers accounts for 76,84%, business add up to 23,16% while the remaining of €/year are categorized as country-wide; no significant value was provided for this case.

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Benefit Category Detailed Benefits Beneficiary %

Consumer Benefits

Energy Savings (€/year) (Calculated for 2.500 customers) Consumer 76,84%


Consumer -

Peak load transfer (€/year) Consumer -

Subtotal 76,84%

Business Benefits


DSO 9,04%


DSO 6,43%

Reduction in electricity technical losses (€/year) DSO 3,18%


Reduction in outage times (thefts, frauds, …) (€/year) n.a. -

Subtotal 23,16%

Other Benefits None - -

Subtotal -

Total 100%

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Benefit Category Detailed Benefits Beneficiary %

Business Benefits

Deferred generation capacity investments (€) n.a. -

Deferred transmission capacity investments (€) n.a. -

Deferred distribution capacity investments (€) n.a. -


Global CO2 reduction (Ton CO2 and € if applicable) Hungarian Government


n.a. -


n.a. -

Subtotal -

Total -

Supply Chain


SC MACRO TIER

RESPONDENT SUPPLIERS BELONGING TO

THE GROUP OTHER SUPPLIERS


competitors; ST BSR

Logistics 1; not supplying competitors

Installation 1; not supplying competitors

Maintenance 1; not supplying competitors


competitors; LT BSR

Data Management

X

The project in progress is being deployed by means of a low Supply Chain (SC) vertical integration. Among the 6 main necessary macro-tiers (Manufacturing and assembly, Logistics, Installation, Maintenance, Data Communication, Data Management), 1 out of 6 (Data Management) is performed internally. As for the other macro-tiers, the majority (3 out

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of 6: Logistics, Installation, Maintenance) of the players are companies belonging to the group, whilst the remaining ones (2 out of 6: Manufacturing and assembly, Data Communication) are not. EDF DÉMÁSZ always (3 out of 3) buys from single suppliers (not supplying competitors) when companies belong to the group, whilst buys both from a single supplier (also supplying competitors) with long-term (LT) Buyer-Supplier Relationships (BSR) currently in place (1 out of 2: Data Communication) and from multiple (also supplying competitors) suppliers with short-term (ST) BSR (1 out of 2: Manufacturing and assembly) when companies do not belong to the group. As far as it concerns the costs related to each macro-tier (basing on the available data), the most relevant ones are Manufacturing and Assembling (55% out of the total cost per unit), and Installation (45% out of the total cost per unit). Data Communication is considerably expensive considering the duration of the project. Logistics and Maintenance are negligible.


In Hungary there is a growing demand and interest from customers’ side to apply leading and cutting edge technologies in households. According to this tendency EDF wants to fulfil customer demand. The smart metering infrastructure provides a massive basis for different services for all the participants in the future.

The Hungarian Energy Office monitors the status of projects. During the preparation of projects different organizations added comments and could tell their opinion regarding smart metering. After closing the projects’ official pilot term the HEO. This will get evaluation about the results, findings, lessons learnt on customer acceptance.

The customer service has been involved in the whole process of project activity. For example providing customers information about the smart metering objectives and possibilities, they receive phone calls and answer the questions. The customer service has not been adapted organizationally wise and there is no plan to do this during the pilot project.

Current status of installation and use of smart metering

The Smart Sinergy Project, a pilot project implementing smart meters solutions in Hungary, is part of a nationwide smart metering programme coordinated by the regulator (Hungarian Energy Office) in which all the distribution companies take part. Started in February 2012 by EDF DÉMÁSZ Hálózat, the Hungarian electricity distributor of EDF DEMASZ Group, this pilot has reached an advanced phase of deployment (95%) and should be completed by the end of December 2013. The number of customers involved (100% residential) is 2.500, although the planned number of meters to be installed is 3330, an issue directly linked to a specific tariff option offered to the consumers by the distributor in which more than one meter can be provided in one single customer site.

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The technical testing of metering solution is not the only objective of the project, because also monitoring customers’ interest, customers’ acceptance and customers’ behaviour is in the scope of the pilot action.

Vulnerable customer focus

Vulnerable customers generally are entitled to get advantageous treatment, such as preferred conditions of debt payment, getting prepaid meter, different conditions of disconnection. In the smart pilot project there is no additional beneficial distinction of vulnerable customers.

Opt out focus

The ratio of customers opting out the smart meter is very low, about 0.3%, reason why in those cases customers who accept it are chosen.

It needs to be noted that the designation of customers - involved in the project and given smart meter - was done by a subcontracted statistical company. The important condition is that the designated customers must represent the entire scale of residential consumers.



Regarding the impact of smart metering deployment on distribution management system, network planning or network maintenance, EDF DÉMÁSZ has no experience yet, as they do not have any productive system yet.

The smart metering system also contributes to the reduction of technical and non technical losses, by collecting data at consumer and feeding points in the area of transformers equipped with PLC. The collected data will be analysed and compared. Having exact data about LV losses, it will be possible to take measures and/or actions to reduce them.

Increasing the number of network data will enable to take proper actions to improve quality of supply; for example, voltage quality or network outages data will support planning and maintenance.

Core of the EV charging infrastructure

EV charging services are not provided during EDF DÉMÁSZ pilot.

Support of Distributed Generation

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All EDF DÉMÁSZ meters are configured to measure two-way energy flows. In case of generation, the meters register separately the consumed and generated active energy. Iskraemeco and Sagemcom meters also register reactive energy. The meter operator and owner is normally the same: the network operator (distribution) company.

Capacity of enabling Demand Response

EDF DÉMÁSZ smart metering system provides the following advanced features related to demand response:

- Customers have access to the Energy Engage web portal (the module of AMI which is intended to show data for customers);

- Customers are entitled to monitor their own measurement data;

- The Energy Engage web portal can represent the following data: aggregated consumption for different intervals (daily, weekly, monthly, specified time range), energy costs for a specified term, comparison functionalities, signals related to a preset power limit, environmental impacts, CO2 emission values;

- Data can be shown either in graph or chart format.

In order to promote energy awareness, conscious use of appliances, active participation of end consumers, and demand response, different TOU (time of use) tariffs are offered to customers as a first approach.

The way users can have access to meter data is a web interface.

EDF DÉMÁSZ is going to perform market tests in the following month to evaluate the potential impact of the solutions on the consumer awareness/customer acceptance, so no results are available yet. No pilots or ongoing projects are developed as well.

There are no initiatives by the Hungarian Regulatory Authority concerning demand response by the moment.

Other advanced metering solutions

EDF DÉMÁSZ is developing a multi-solution project. The electricity meters are equipped with MBus interface, enabling the meter to connect sub meters. In the pilot project, 8 smart gas meters and 50 smart water meters will be installed, without an existing electricity smart metering infrastructure.

The agents responsible for each activity are:

- Each utility company purchases its own smart meter.

- Each company is responsible for its own meter installation and maintenance.

- The meter reading and data collection will be performed by our AMI infrastructure.

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- Different measurement points and identifiers were created during the system configuration.

- Measurement data will be collected by the electricity company (EDF DÉMÁSZ) and transferred via FTP for both utility companies.

A Cost/benefit Analysis (CBA) for metering solution is carried out in the previous phase of the project. A two-level comparison (qualitative and quantitative analysis) has been prepared in order to make the choice among the selected models easier. Direct and indirect costs have been quantified, as well as benefits and estimated investment needs (quantitative analysis); furthermore, within the framework of a qualitative analysis, the effect of those factors were to be analysed at a later phase of the project, when the selected models are known.

The CBA presented in the Preliminary Report was prepared, primarily, to support the selection from the different models, so it cannot be considered as an overall analysis. The model did not evaluate the following topics:

- External benefits of smart metering in the field of energy savings and reduction in the emission of green house effect gases (GHG);

- The distribution of costs and benefits among the different stakeholders;

- Changes in the different models in case key parameters change (sensitivity analysis/tests).

The CBA presented in this Final Report, has been significantly amended both in the case of the number of quantified parameters and in the case of the comparisons of the different models and model variants.

The model, taking into consideration the number of parameters used, is appropriate for performing sensitivity analysis/tests. Several of these tests will be presented in this study.

During model definition, we relied on five data sources:

- Data from the Hungarian Energy Office;

- Data provided by the industry players (distributors, trading licensees/universal service providers, telecommunication service providers) – data collection organized by the consultant;

- Relevant information and data from international studies (benchmark);

- Remarks from the cluster workshops and written comments to the Preliminary Report;

- Information data obtained from the DSOs on the currently used ’traditional’ meters regarding the aging of the meters and energy consumption of the examined consumer segment in relation with the number of meters installed. During the

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introduction of the different model parameters we will mention the source of the given parameter and our remarks related to the relevance of it.

There is not a deadline for a future full roll out by the moment. The National Regulatory Authority has not yet defined a minimum set of functionalities to be provided. Regarding value added services, EDF DÉMÁSZ provides the Energy Engage web portal, the web interface aforementioned.

Conclusions on Hungary Even if in Hungary there is no legislation regarding the introduction of smart meters, the country has taken certain steps in ensuring alignment with the current EU directives. At the moment only pilot projects are available as there is no national electricity smart metering implementation (rollout), nor any data about the status of other distribution companies. The responsible for meter installation, meter maintenance, meter reading and meter data management is the distribution company based on territorial principle. The distribution company owns the meters and measurement data too. In Hungary there are 6 distribution companies; one of them has replied to the questionnaire: EDF Dèmàsz. The average residential contractual power is 4,6 kW while the average residential yearly consumption is 1337 kWh. Communication between meters and concentrator is based on DLMS/COSEM over PLC or GPRS, while between concentrator and data collecting system is based on TCP/IP over GPRS. Since in Hungary there is a growing demand and interest from customers’ side to apply leading and cutting edge technologies in households, the customer service has been involved in the whole process of project activity. The main benefits of the smart metering infrastructures regard a better monitoring of the grid, with the aim of improve the quality of the service, and the operability of the grid itself, and to get better scheduled maintenance and the upgrading of the grid. Support to distributed energy resources is taken into account, while EV charging services are not in the company scope. In order to promote energy awareness, conscious use of appliances, active participation of end consumers, and demand response, different TOU (time of use) tariffs are offered to customers as a first approach. Nevertheless, there are no initiatives by the Hungarian Regulatory Authority concerning demand response by the moment. EDF DÉMÁSZ is developing a multi-solution project.

3.5 Netherlands


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National Regulation on smart meter At the end of 2010 out of eight DSOs two were not unbundled. The other six are fully unbundled from the integrated companies (ownership unbundled). This situation developed due to a ruling of the Court of Appeal on 22nd June 2010 which stated that the legal requirement for integrated energy companies to separate their network management companies from their production, trade and supply companies is contrary to European law. This so-called 'group ban' is contained in the Dutch Unbundling Act (Wet onafhankelijk netbeheer) of November 23 2006 (State Gazette 2006, 214). The State has lodged an appeal against the ruling before the Supreme Court. This group ban is more restrictive than the unbundling requirements in the European Commission's third legislative package, whereby ownership unbundling is an alternative option for transmission system operators only. In the Netherlands the gas and electricity TSO's (GTS and TenneT respectively) are owned by the State. Dutch energy companies Essent, Eneco and Delta argued before the Court that the group ban violates European law, particularly the free movement of capital laid down in Article 63 Treaty on the Functioning of the European Union (TFEU). The group ban, among other things, precludes investors engaged in energy activities from other Member States from investing in the Dutch distribution sector. The Court agreed and ruled the group ban incompatible with the free movement of capital. As a consequence of the ruling the group ban has been put on hold for the moment. The same goes for certain provisions restricting the permitted activities of the network manager. The Minister of Economic Affairs has stated that, pending the proceedings before, the Supreme Court unbundling of integrated energy companies will not be enforced. The ruling has come as a shock to the energy companies, their shareholders and policy makers. The shareholders of Nuon and Essent had already sold the production, trading and supply activities to RWE and Vattenfall respectively. The remaining two integrated companies, Eneco and Delta, have put their advanced separation efforts on hold. If the Supreme Court upholds the ruling of the Court, all these companies may submit claims for damages21. Pending the proceedings before the Supreme Court, the State and the Dutch Competition Authority (NMa) have started to encourage Eneco and Delta to separate voluntarily. The Dutch Supreme Court in February 2012 asked the EU court whether the rules are in line with the 28-nation bloc’s law. Eneco has said that a forced unbundling would pose a threat to the company’s sustainability strategy. The latest development (October 2013) on the topic is that Dutch utility unbundling rules may be lawful as per the EU court: “Maintaining undistorted competition in order to protect consumers and ensuring security of energy supply constitute overriding reasons in the public interest,” the EU Court of Justice in Luxembourg ruled today, according to a

21

The Netherlands: No end to the ownership unbundling saga - Jan Erik Janssen and Stephanie Goossens http://www.expertguides.com/default.asp?Page=9&GuideID=238&Ed=130

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statement. Restrictions should be “appropriate to the objectives pursued” and must not “go beyond what is necessary,” the ruling said22. Despite the complications regarding the unbundling The Netherlands has established itself as a dynamic actor on the smart metering topic. In November 2010 the Dutch Parliament passed a revised bill that sets the legal framework for a voluntary rollout of smart meters (before a mandatory rollout was considered, but latter dismissed). The grounds for the revised bill on smart metering were the strong debates and lobbying of the National Consumer’s Association Consumentenbond and privacy concerned groups. The actual legal framework does not allow for enforcement measures for the acceptance of the smart meter. The role of the government is to focus on stimulation, information and persuasion of smart meter acceptance. Areas for attention with respect to policy targets are the acceptance of the smart meter, the effective use of the smart meter and an efficient rollout of the smart meter. Also in 2010 KEMA has revised the cost benefit analysis following three important points that needed to be taken into consideration:

The smart meter will only be read once every two months – as standard reading.

The consumer will have the opt-out option

The needed (possible) measures to be taken by the Dutch government in order to enhance social costs and benefits

Considering a reference situation of almost 100% acceptance of the smart meter and 100% standard readings the 2010 CBA23 concluded there is positive business case with a net present value of 770 million EUR. After the 2010 approval of the voluntary rollout, the two year piloting actions have begun in the Netherlands. The experiences gathered from the piloting actions will be evaluated and based on them a decision will be taken on the final rollout by 2020. The Dutch Office of Energy Regulation as part of the Netherlands Competition Authority - Nederlandse Mededingingsautoriteit - NMa is one of the NRA in the EU which clearly states and delivers on its mission to create opportunities and options for business and customers alike24 . Together with the Consumer Authority and the Authority for Post and Telecommunications, Energiekamer (regulator for DSOs) has initiated Consuwijzer. Consuwijzer is the government information desk that provides practical advice to consumers regarding their rights as a consumer. In 2010, consumers consulted the website of ConsuWijzer, over two million times. Also, 10,000 consumers received individual advice with regard to their rights on the subject of energy. In 2010, most complaints and inquiries were related to sales activities (such as telephone sales and canvassing). Also billing related issues such as wrong metering data and unclear

22

JUDGMENT OF THE COURT (Grand Chamber) 22 October 2013 C 105/12 to C 107/12 - http://tinyurl.com/phagr5w 23

Smart Meters in The Netherlands 2010 - http://www.rijksoverheid.nl/documenten-en-publicaties/rapporten/2010/10/25/smart-meters-in-the-netherlands.html 24

NMa - https://www.acm.nl

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billing, were important sources of complaints and inquiries. As a result Energiekamer has, drawn up a Code of conduct on customer acquisition and produced a Guideline on billing25 . The Dutch tariff system is primarily based on fixed rates. The only available tariff scheme that could be considered as a basic and static form of demand response is the option to choose for a meter that allows a fixed switch between two tariffs: day- and night/weekend tariffs. It is expected that the roll out of smart metering will stimulate a flexible tariff schemes.

Distributors and customers shares for each distributor In The Netherlands there are eight DSOs.

Distributors replying to the questionnaire For this country analysis two DSOs have replied: Enexis BV and Liander.

3.5.1 Enexis BV

The Enexis smart meter project has started in 2011 and it’s expected to finish at the beginning of 2020 where the roll out cumulated number of installed electric and gas meters must be about 4.160.000. The project is a rollout that, at the moment, involves about 2.600.000 residential customers. Overview of the Power Grid

Yearly energy distributed (TWh) n.a.

HV,MV and LV voltage levels n.a.

Number of HV/MV substations;

53000

Number of MV/LV substations;


Average residential yearly consumption (KWh) n.a.


Enexis BV: AMI Architecture

The Enexis BV AMI architecture is shown in Figure 1.

25

ERGEG - 2011 National Report of Energiekamer to the EC -http://tinyurl.com/pp85vu8

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Smart meter communicates with Data Concentrator via PLC G3, or directly with the head end via GPRS. Data concentrator communicates with the head end via GPRS. The remote synchronization of clock is managed through NTP. The alarm mechanism is generally pull type. Data are retrieved from meters six time a year with a reading success rate around 98%. The amount of data in each reading operation regards four energy register and three low profile.

Figure 1: ENEXIS BV AMI

Enexis BV: Main Features of Electricity Smart Meters (single and three phases) Single phase and three phase meter share the same communication technology. The single phase meter self-consumption is 2W/10VA in case of active communication, but no specification is available when communication is not active. On the other side the three phase meter self consumption is 4W/20VA in case of active communication but with no data available about the consumption in case of not active communication. The meter is provided with a switchgear compliant with DSMR 4.04 standard.


Meter average life 15

Presence of internal switchgear Yes there is a switchgear: a non-accessible breaker that is

compliant with DSMR 4.04 standard

List of international standard that IEC 62056

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meter is compliant to EN 13757-2:2004

EN 13757-3

EN 13757-4,

EN 60870-5-1

EN 60870-5-2

Enexis BV: Main Functions of Electricity Smart Meters (single and three phases)

Single phase and three phase meters have identical main functionalities.

SINGLE PHASE

THREE PHASE

Frequency for reading Standard 6 x a year

Active energy measurement Bi-directional

Reactive energy measurement Not detected


Standard 2 2 standard programs, to

be increased to 8


Standard 2 2 standard programs, to

be increased to 8


Standard 2 2 Standard programs, to

be increased to 8


8

Possibility to remotely manage supply contracts Yes


Load control support No

The meter record events in an event log Yes, events recorded

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Yes

Demand management feature implemented No

Prepayment management implemented No

Local interfaces P1 port

Possibility to remotely download firmware Yes


Costs & Benefits

No available data.

Supply Chain


SC MACRO TIER

RESPONDENT SUPPLIERS BELONGING TO THE

GROUP OTHER

SUPPLIERS

Manufacturing X

Logistics X X

Installation X X

Maintenance X

Data Comm. X X

Data Management X

The project in progress (initial stage of a roll-out) is being deployed by means of an extreme Supply Chain (SC) vertical integration, combined with the use of suppliers not belonging to

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the group. Among the 6 main necessary macro-tiers (Manufacturing and assembly, Logistics, Installation, Maintenance, Data Communication, Data Management), 5 out of 6 (Logistics, Installation, Maintenance, Data Communication, Data Management) are performed internally. In addition, Manufacturing and assembly, Logistics, Installation, and Data Communication are also performed by suppliers not belonging to the group. As far as it concerns the costs related to each macro-tier within the project in progress, no information is provided.

SC of the Roll-out:

SC MACRO TIER

RESPONDENT SUPPLIERS BELONGING TO THE

GROUP OTHER

SUPPLIERS

Manufacturing X X

Logistics X X

Installation X X

Maintenance X

Data Comm. X X

Data Management X

The SC for the progress of the roll-out is expected to be the slightly different from the current one, with even higher level of vertical integration (complete integration), always supplying Manufacturing and assembly, Logistics, Installation, and Data Communication also from suppliers not belonging to the group. As far as it concerns the costs related to each macro-tier within the progress of the roll-out, no information is provided.


On a national level, as part of the monitoring of the pilots, tests with provisioning empowering devices (displays, energy-stick with connection to home-computer etc) in measuring differences in electricity consumption with consumers with traditional meters or smart-meters without devices are carried out. Results look promising and are expected in Q3 2013. Having a well structured agenda for consumer involvement in The Netherlands it seems all the DSOs questioned have taken the same line of actions when it comes to involving their customers.

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ENEXIS’s initiatives include providing displays and other P1 (Consumer port) devices (on a small scale) to customers and periodically attitude surveys are conducted. Also on a regular basis they are holding ‘round-tables’ with customer organizations and other stakeholders (DSO’s , Energy Suppliers, NRA) on the SM related topics. The small-scale roll-out is monitored by the NRA in order to get an overview whether the Grid-operators and energy suppliers are ready to move forward to a large-scale roll-out. Customer Satisfaction (for instance on installation process, ease of application smart-meters) is part of the monitoring. The small-scale roll-out is monitored by the NRA in order to get an overview whether the Grid-operators and energy suppliers are ready to move forward to a large-scale roll-out. Customer Satisfaction (for instance on installation process, ease of application smart-meters) is part of the monitoring. NMa (NRA) monitors customer satisfaction by several sites and contacts with the DSO’s and Energy Suppliers (see also the sites: www.consuwijzer.nl and www.agentschapnl.nl) Aside from its usual website (www.enexis.nl) ENEXIS has taken a step forward and developed the concept and website “Your Energy Movement” - www.jouwenergiemoment.nl where all the actions taken by the company in the piloting phase are explained step-by-step and has the declared aim to investigate if the citizens are willing to participate in supporting the development of the energy grid of the future. The emphasis in attracting the consumers is on the environment and partly the money saving opportunity by introducing the renewable sources and also using energy as efficiently as possible.


The Enexis BV smart metering project has started in 2011 and it is expected to finish

deployment by 2020. At current time it involves about 2.600.000 customers, 95% of which

are residential. In case of rollout, it is foreseen that 4.160.000 meters will be installed by

2020.


Already with traditional meters, there is legislation to protect vulnerable customers.

Opt out focus

As described above there is no mandatory obligation for customers to have smart meters

installed.

The current state of smart metering services in The Netherlands is also closely related to the four legal options for a consumer in accepting a smart meter:

1.The option to refuse the installation of a smart meter and keep the ‘traditional’ meter;

2.The option to have a smart meter fitted (or once it has been installed), but opt out of sending your meter readings automatically (smart meter functions as a traditional meter, a meter reader is still required);

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3. The option to have a smart meter fitted, but with a limited set of automatic meter reading capabilities of which the most important are: final billing in case of switching energy supplier or remove to a new house, once a year for annual billing and bi-monthly meter readings for interim energy advice.

4. The option to have a smart meter fitted, with full automatic smart meter reading. This is (of course) the preferred option for the government and energy market players.



No information provided

Core of the EV charging infrastructure Enexis´ smart metering solution deals with innovative services for EV charging, enabling services such as Smart charging and vehicle to grid services. Support of Distributed Generation

Regarding DER integration, Enexis is responsible for metering data by domestic end customers / prosumers. Capacity of enabling Demand Response Enexis smart metering system provides a display as a feature to enable demand response functionalities. In order to promote energy efficiency and demand response, Enexis has cooperated with some initiatives, such as Quby, Plugwise and pilots in Breda / Zwolle (see also www.jouwenergiemoment.nl). They have also participated in Power Matching City 2 in Hoogkerk. The pilots investigate customer behaviours in combination with price incentives. The costumer could use different interfaces to get access to the meter data: web interface, TV, smartphones, dedicated displays, personal computer or entertainment equipment.

Concerning the initiatives carried out by the National Regulatory Authority (NRA) to promote demand response, DSOs are regulated on price caps; CPI-X regulation. NRA is closely and informally involved in the progress of the pilots, but until now the Dutch Regulatory Authority has not initiated any initiative on demand response. The ministry of Economic Affairs has initiated a research report on “recommendations to initiate smart grid pilot projects in relation to laws and regulation”.

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Other advanced metering solutions Based on Enexis´ metering infrastructure model, the responsible ones for meter manufacturing are meter suppliers, while the DSO is the responsible for meter installation and maintenance, meter reading (after 01-04-2013 energy Supplier), communication devices manufacturing (e.g. concentrators) installation and maintenance, central system management, and data management. Enexis has started their roll out plan, and they expect to install 200.000 smart meters by 2013. Regarding cost benefit analysis for metering solution, the Dutch Regulatory Authority has published a report, available at www.kema.com. The minimum sets of functionalities defined by the NRA to be provided are DSMR, NTA8130 and AMvB law. The deadline for 80% full roll out is 2020, by a positive evaluation in 2014.

The advanced metering solution includes the provision of value added services (not specified).

3.5.2 Liander

The Liander smart meter project has started on January 2012 with a small scale roll-out This rollout involves a number of residential customers in the range 225.000-275.000 for electricity meters and gas meters. In this small scale roll out concentrators are not used because, by the moment, communication with central system is directly done by GPRS. From 2014 to 2020, the project will continue in a large scale roll-out with a target of 80% of smart meters installed in 2020 (electricity and gasmeters); resulting in, in total, approximately 2.3 mln electricity- and 1.6 mln gasmeters installed by 2020. From 2015 and further, CDMA 450mhz will be used as main communication technology instead of GPRS. The average residential contractual power is in the range of 7-17 kW and, while the average residential yearly consumption is 3300 kWh.

http://www.kema.com/

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HV,MV and LV voltage levels HV: >35kV, MV: 1-20kV, LV: <1kV

Number of HV/MV substations;

Number of MV/LV substations; About 45.000


Average residential yearly consumption (KWh) 3300


Liander: AMI Architecture Energy suppliers will send a request for data to a central P4 system in the Netherlands. Based on the EAN central P4 will forward the request to the Central Acces server (CAS). The Grid Operator (in this case Liander) will validate the request and forward the request to the Head End (HE) system. The HE will request the meter for the data. The meter will be woken up during night time and returns the requested data to the HE. The CAS request for available data end creates the answer message if the supplier request for the results on the requested data. The communication between smart meters and data collector is based on DLMS over GPRS. Data collector should be able to manage 3.000.000 of electricity meters and 2.500.000 gas meters, and is located in the Liander data center.

Liander: Main Features of Electricity Smart Meters (single and three phases) Single phase and three phase meter share the same communication technology. The single phase meters have a typical power consumption of 4 W in case of active communication. On the other side when communication is not active, the voltage circuit is less than 2 W and the apparent power is about 10VA. The meter doesn’t have any electrically protective device but has an internal breaker - not physical accessible – that can be switched on and off by a button on the meter or remotely by the head end system. The maximum cut-off current is 80A both for single phase and three phase meters. The meters is provided with a supercap as backup power supply and presents an LCD display with custom icons and numeric fields.


Meter average life 15 (minimum required)

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Yes, breaker. Not physical accessible, only by buttons at the meter or remote by Head-End (HE). From 2016 and further, there will be no breaker in the smart meter anymore, due to change of legal smart meter requirements in 2013


Smart Meters are supplied by international meter-suppliers, are MID approved and meet international standards.

Liander: Main Functions of Electricity Smart Meters (single and three phases) Single phase and three phase meter have identical main functionalities.


Frequency for reading Daily, monthly and 15 minutes intervals

Active energy measurement Yes

Reactive energy measurement Not detected


>2


Adjustable


Flat tariff or two tariffs for both directions


Flat tariff or two tariffs for both directions

Possibility to remotely manage supplying contracts

Yes


No

Load control support Not used, but a limiter option is used

The meter record events in an event Yes, it can remotely be read out by the Head-end

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log



system. Logs: alarms as tamper detect, Mbus alarms


Yes, power outages and Voltage sags and swells


No

Pepayment management implemented

No

Local interfaces P0 maintenance, P1 local consumer port (Display/devices/HAN), P2 mbus devices (Gasmeter, other meters), P3 Central systems


Yes


Costs & Benefits

No available data

Supply Chain





competitors; ST BSR

Logistics X X

Installation X 3-5; also supplying

competitors; LT BSR

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Maintenance X


competitors; LT BSR

Data Management X

The project in progress is being deployed by means of a relevant Supply Chain (SC) vertical integration. Among the 6 main necessary macro-tiers (Manufacturing and assembly, Logistics, Installation, Maintenance, Data Communication, Data Management), 2 out of 6 (Maintenance, Data Management) are performed completely internally, and 2 out of 6 (Logistics, Installation) are performed both internally and by suppliers not belonging to the group. As for the other macro-tiers, both Manufacturing and Data Communication are performed by suppliers not belonging to the group. Liander buys from both multiple suppliers also supplying competitors (Manufacturing and Installation), and from a single supplier also supplying competitors (Data Communication). Long-term BSR are already in place for Installation and Data Communication; they will be set also for Manufacturing in the near future. As far as it concerns the costs related to each macro-tier for the current project (basing on the available data), the most relevant ones are Manufacturing and Assembling (64% out of the total cost per unit), and Installation (36% out of the total cost per unit). Logistics, Maintenance, Data Communication and Data Management are negligible. The SC for the future roll-out is expected to be the same as the one in progress. The costs related to each macro-tier within the roll-out, no information is provided.


On a national level, as part of the monitoring of the pilots, tests with provisioning empowering devices (displays, energy-stick with connection to home-computer etc) in measuring differences in electricity consumption with consumers with traditional meters or smart-meters without devices are carried out.

Having a well structured agenda for consumer involvement in The Netherlands it seems that all the DSOs questioned have taken the same line of actions when it comes to involving their customers.

LIANDER’s initiatives include providing displays and other P1 (Consumer port) devices (on a small scale) to customers and periodically attitude surveys are conducted. Also on a regular basis they are holding ‘round-tables’ with customer organizations and other stakeholders (DSO’s , Energy Suppliers, NRA) on the SM related topics.

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The small-scale roll-out is monitored by the NRA in order to get an overview whether the Grid-operators and energy suppliers are ready to move forward to a large-scale roll-out. Customer Satisfaction (for instance on installation process, ease of application smart-meters) is part of the monitoring. NMa (NRA) monitors customer satisfaction by several sites and contacts with the DSO’s and Energy Suppliers (see also the sites: www.consuwijzer.nl and www.agentschapnl.nl)

When it comes to Customer Service adaptation this has not been implemented as the smart-scale rollout does not require this. In the opinion of the DSO smart meters do not really increase number of complaints/questions on the customer service department at this stage of the roll-out (relative small numbers) and plenty of information is offered via online communication www.liander.nl. But in the same time towards the large-scale roll-out, expansion of the customer-service department is foreseen by the enquired DSO.


The Liander smart meter project has started on January 2012 with a small scale roll-out This rollout involves a number of residential customers in the range 225.000-275.000 for electricity meters and gas meters. In this small scale roll out concentrators are not used because, by the moment, communication with central system is directly done by GPRS. From 2014 to 2020, the project will continue in a large scale roll-out with a target of 80% of smart meters installed in 2020 (electricity and gasmeters); resulting in, in total, approximately 2.3 mln electricity- and 1.6 mln gasmeters installed by 2020. From 2015 and further, CDMA 450mhz will be used as main communication technology instead of GPRS.

During the small-scale roll-out (2012-2013) Liander rolls out in any case within the statutory categories:

Newly build;

Renovations;

Customer demand;

Regular replacements of meters;

Pilot project demonstrating the social value of the smart meter;

Learning, system development and preparing for large scale deployment;

In case of small-scale roll-out, it has been estimated a total number of smart electricity meters that range from 300.000 up to 350.000.


Already with traditional meters, there is legislation to protect vulnerable customers.

Opt out focus

As described above there is no mandatory obligation for customers to have smart meters

installed.

http://www.consuwijzer.nl/

http://www.agentschapnl.nl/

http://www.liander.nl/

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The current state of smart metering services in The Netherlands is also closely related to the four legal options for a consumer in accepting a smart meter:

1. The option to refuse the installation of a smart meter and keep the ‘traditional’ meter; 2. The option to have a smart meter fitted (or once it has been installed), but to opt out

of sending your meter readings automatically (smart meter functions as a traditional meter, a meter reader is still required);

3. The option to have a smart meter fitted, but with a limited set of automatic meter reading capabilities of which the most important are: final billing in case of switching energy supplier or remove to a new house, once a year for annual billing and bi-monthly meter readings for interim energy advice.

4. The option to have a smart meter fitted, with full automatic smart meter reading. This is (of course) the preferred option for the government and energy market players.



Regarding the impact on distribution management system, network planning or network maintenance, Liander has not yet developed anything particular, but it is expected to be done in the near future as installed base of smart-meters has reached a certain volume.

Core of the EV charging infrastructure Liander´s smart metering system deals with innovative services for EV charging, with initiatives like the provision of a customer port (P1) connected to chargebox in garage from customers, providing information to the chargebox for maximum possible power consumption. Support of Distributed Generation

No information provided Capacity of enabling Demand Response In the Netherlands, the GRID-operator is responsible for roll-out and maintenance of the smart meter system. Smart meter enables additional services for customers, but these services have to be developed by third parties: they are not a direct task for DSO. Smart-meter contains a customer port P1 (Consumer) to enable specific consumer services for other third parties. The scope of this standard is the end-consumer (P1) interface for:

- Residential electricity meters;

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- Residential thermal (heat & cold) meters; - Residential gas meters and gas valve; - Residential water meters;

This companion standard focuses on the P1 interface for gas, gas valve, thermal (heat/cold), and water meters. There is no separate interface for electricity meters since these meters are technically part of the metering system.

The goal of this companion standard is to reach an open, standardized protocol implementation and functional hardware requirements related to the communication between several types of Service Modules and a Metering System. Any specification in this standard is intended to encourage suppliers to develop their hardware and software in a common direction. Standardized protocols and hardware specifications are referred to as much as possible. This companion standard is the result of a combined effort of the major Dutch grid operators. Liander has conducted market tests to evaluate the potential impact on the consumer awareness and acceptance. On a national level, as part of its small-scale roll out, tests with provisioning empowering devices (displays, energy-stick with connection to home-computer, etc.) measuring differences in electricity consumption with consumers with traditional meters or smart-meters without devices, are carried out. Results are expected in Q3 2013.

Other advanced metering solutions

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Regarding other energy carriers, gas meters will be read out by the E-meter. In almost every case (electricity and gas), they will be installed at the same time, so no legacy E-meters will be used. Dutch grid-operators mainly do both electricity and gas in the same way. Dutch smart metering system is for both electricity and gas, and they are rolled out in almost the same amount as Smart-electricity meters. Because of Regulatory obligations, Dutch meters are provided with a mandatory P2 port on which gas meters or other smart meters (water, heat) can be connected. Gas meters connected to electricity meters are almost a standard (few exceptions), as the gas meters are mostly owned by the same DSO (like the electricity meters) and rolled-out together with electricity meters..Liander has carried out only some small pilots on heat and water metering. Dutch Regulatory Authority has set mandatory functionalities for smart meters: electricity (e) and gas meters (g):

- Actual meter readings (e/g) - Register and reading demands (e/g) - Firmware update (e/g) - Switch/shut down (e/g) (removed from mandatory functionalities in 2013) - Limitation of capacity (e) (removed from mandatory functionalities in 2013) - Safe switch on of gas meter (g) (removed from mandatory functionalities in 2013) - Display status measurement system (e/g) - Quality of delivery (metrology through P3 (e) - Delivery tariff through P1 (e) - Exchange of quality and status (e) - Fraud detection (e) - P1 (e/g) - P2 (e/g) - Exchange status (g) - Communication through measurement system E (g) - Security (e/g) - Quality of delivery though P1 (e) - Admin-off on display - Local temperature correction (g) - Open international standards (e/g) - Actual capacity (e) - Fraud detection (g) - Communication log (e/g) - Modular communication module (e)

The deadline established for smart metering roll out is 2020, meaning that an 80% of the meters must be installed by this time (according to EU directive).

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As advanced services provided by the meters, consumer port (P1) provides data and enables value added services. Provision of smart devices is carried out in small pilots. However, there is a discussion in the Netherlands whether this should be a task of a regulated DSO. So far, it is not.

Conclusions on Netherlands The Netherlands has established itself as a dynamic actor on the smart metering topic. In November 2010 the Dutch Parliament passed a revised bill that sets the legal framework for a voluntary rollout of smart meters. The grounds for the revised bill on smart metering were the strong debates and lobbying of the National Consumer’s Association Consumentenbond and privacy concerned groups. The actual legal framework does not allow for enforcement measures for the acceptance of the smart meter. The role of the government is to focus on stimulation, information and persuasion of smart meter acceptance. Areas for attention with respect to policy targets are the smart meter acceptance, the effective use and an efficient rollout of the smart meter. After the 2010 approval of the voluntary rollout, the two year piloting actions have begun in the Netherlands. The experiences gathered from the piloting actions will be evaluated and based on them a decision will be taken on the final rollout by 2020. In the Netherlands there are eight DSOs, of which 2 has replied to the questionnaire: Liander and Enexis BV. The communication used in the analysed projects varies among the projects. In the case in which the concentrator is present, the communication between it and the meter is based on G3 PLC, while the communication between concentrator and data collector is based on GPRS. The same technology is used also in case meters are connected directly with data collector and the communication is based on DLMS over GPRS. Liander will switch from GPRS to CDMA 450mhz as the main communication technology used. In both cases, the budget for the project is mainly funded by the (regulated) DSO’s. The customer involvement is done in both cases by initiatives that include the provision of displays and other P1 (Consumer port) devices to customers, and making periodically attitude surveys. Also, on a regular basis, ‘round-tables’ are organized with customer organizations and other stakeholders (DSO’s , Energy Suppliers, NRA) on the SM related topics. Regarding the impact on distribution management system there is not enough information available, but it is supposed to be an improvement of the quality of the service, grid operation, maintenance scheduling and of the grid upgrading. Both projects take into account the integration of EV recharge services, as well as the integration of DER by managing the metering data of the prosumer.

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In both projects smart meters enable additional services for customers (e.g. demand response), but these services have to be developed by third parties (and not directly by the DSO). In Liander project, gas meters will be read out by the E-meter.

4 MAIN FINDINGS AND CONCLUSIONS

From the analysis of the 7 projects taken into account, it’s possible to extrapolate the following findings:

In 3 out of 5 European countries analysed, there is a regulatory framework that states a roadmap for the smart metering. However, in the remaining two countries – Hungary and Belgium – the topic is of high interest, and the necessary steps are being taken in order to ensure the alignment with the current EU directives.

The main differences between projects are the maturity of the technology and the number of meters already installed. Projects differentiate themselves in terms of number of customers’ involved, as well as the communication technology and communication protocol used. However, it’s possible to find a common approach in communication solutions adopted.. The most used communication protocols are DLMS/COSEM and TCP/IP while the most used technologies for communication between meters and concentrators are PLC and GPRS. The functions provided are very similar.

Regarding the sources of funding, all projects are mainly publicly funded. In one case fundings are both public and private, while in one case there is not enough information available.

Focusing on customers’ involvement, it is observed that in some cases companies running the smart metering projects adopt a clear strategy targeting end-users engagement, while in other cases the focus is more technology-oriented. The initiatives to engage the consumers in the smart metering implementation range from basic informative letters on the matter (including updates throughout the process), to round-table meetings with the stakeholders and to large-scale surveys and Customer Service platforms with the aim of giving customers ways to share their opinions and enhancing their interaction with the smart meter.

The main benefit brought by smart meters seems to be the possibility of a better network monitoring, to improve the planning and maintenance of the grid and to improve the quality of supply as well as the overall efficiency, and the possibility of reduce both technical and commercial losses. Another important benefit is the

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reduction of reading and operation costs due to remote reading and remote operations (contractual changes, connect/reconnect). Also, DSOs are much interested to the possibility of a better integration of the distributed energy resources, and the EVs charging infrastructure. The possibility to implements some demand response strategy is also taken into account.

The multimetering is taken into consideration in some projects.

Communication technology In the following table the summary of the communication technology and protocol adopted in each project analysed in D2.1 and in D2.2 is shown for the three main communication paths

(home <-> meter, meter <-> concentrator, concentrator <-> data collector). Note that in

some cases the meter is directly connected with the data collector.

PROJECT

COMMUNICATION PATH

home <-> meter meter <-> concentrator concentrator <-> data collector

EANDIS RS-485 or ETH Technology: PLC-PSK | ETH

Protocol: DLMS | TCP-IP Technology: GPRS Protocol: TCP-IP

EDF RS-232/485

Technology: G3-PLC Protocol: DLMS-COSEM

Technology: GPRS Protocol: TCP-IP

Technology: GPRS Protocol: DLMS-COSEM

EDP RS-485/MODBUS to connect to an external communication module

Technology: PLC | GPRS Protocol: DLMS-COSEM | TCP-IP


ENDESA / Technology: PLC-BPSK

Protocol: METERS and MORE Technology: GPRS Protocol: TCP-IP

ENEL optical pulse output (1 pulse per

kWh) Technology: PLC

Protocol: telegestore protocol Technology: GPRS Protocol: TCP-IP

ENEL MUNTENIA

optical pulse output (1 pulse per kWh)

Technology: PLC Protocol: telegestore protocol


ENEXIS P1 port

Technology: G3-PLC Protocol: DLMS-COSEM



ERDF numerical local interface (TIC) Technology: G3-PLC

Protocol: / Technology: GPRS

Protocol: /

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EVN ZigBee Technology: GPRS Protocol: TCP-IP

FORTUM Optical pulse output (1 to 1000

pulse per kWh) Technology: PLC

Protocol: echelon Technology: 3G Protocol: GPRS

HC / Technology: PLC Protocol: PRIME

Technology: G3 or LAN Protocol: FTP

IBERDROLA / Technology: PLC Protocol: PRIME

Technology: PLC, GPRS or ADSL

Protocol: IEC 60870-5

LIANDER P1 port Technology: GPRS (and CDMA 450mhz in near future) Protocol: DLMS- COSEM (application layer) and TCP-IP

STROMNEtZ local customer interface

Technology: PLC Protocol: /

Technology: GSM, GPRS or LAN Protocol: /

Technology: GSM Protocol: /

GNF / Technology: PLC Protocol: PRIME

Technology: 3G or GPRS Protocol: /

It can be seen that the most used communication technology is based on PLC for the communication between meters and concentrator, and on GPRS/GSM between concentrators and data collector. GPRS/GSM is also used for the communication between the data collector and the meters that are directly connected with the data collector itself. This is due to the fact that both the PLC and GSM/GPRS technology are well known, robust and are relatively simple to implement thanks to the existing infrastructure. It should be emphasized, however, that in case of GSM/GPRS technology, the DSO must lean normally on a telecommunication provider, while in case of PLC technology the DSO is totally independent of any third-party. Regarding the communication protocol it should be noted that, in case of project in full roll-out phase or already rolled-out, the protocols used are such as to respond to requirements that, though meeting the minimum ones, in some cases requirements are not able to meet those provided by the mandate 441. In projects in R&D or pilot phase this is not true simply because they started after, so they are up to date with the new requirements. The interfaces between the smart meter and the home deserve a separate discussion. The great variability in the available interfaces that can be noted in the table is due to the fact that has not yet been well defined, at EU Commission level, which data must be exchanged from the meter to the Energy Management System of the home and how they must be exchanged. So every DSO uses its preferred technology. Also, in 4 projects, this link is not even considered. Smart metering functionalities

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The following table maps smart metering functionalities reported in the 2012/148/EU Recommendation26 versus the Meter on projects. Each DSO has been called to comment the table below in order to allow them to explain whether or not their smart metering system is compliant with 2012/148/EU. Their reply will be presented in the next update of the deliverable.

Empty Yes Not

clear

For the customer

Provide Readings directly to the customer and any third party designated by the consumer

2 12 1

Update the readings referred to in point (a) frequently enough to allow the information to be used to achieve energy savings

2 12 1

For the metering operator

Allow remote reading of meters by the operator 3 12

Provide two way communication between the smart metering system and external networks for maintenance and control of the metering system

2 13

Allow readings to be taken frequently enough for the information to be used for network planning

2 13

For commercial aspects of energy supply

Support Advanced tariff systems 2 13

Allow Remote on/off control of the supply and/or flow or power limitation

3 12

For security and data protection

Provide secure data communications 2 13

Fraud prevention and detection 2 13

For Distributed generation

Provide Import/export and reactive metering 4 11

26



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Special care will be taken to explain the second functionality, for which each DSO has been asked to comment the frequency that consumption data is made available to the consumer (every 15 min, 30 min, 60 min, the next day…etc.) - and not only to the back office/DSO as well as if they smart metering system supports to advanced tariffs schemes.

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Copyright

“Copyright and Reprint Permissions. You may freely reproduce all or part of this paper for non-commercial purposes, provided that the following conditions are fulfilled: (i) to cite the authors, as the copyright owners (ii) to cite the Meter ON Project and mention that the European Commission co-finances it, by means of including this statement “Meter ON. Energy Project No 308794. Funded by EC” and (iii) not to alter the information.”

Analysis of Smart Metering projects

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