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Autorità per l'energia elettrica e il gas 1
ELECTRICITY QUALITY OF SERVICE REGULATION IN ITALY
Ferruccio VillaQuality and Consumer affair Department
Head of Electricity Quality of SupplyHead of Electricity and Gas Smart
Study visit of FTSMilan, 4 March 2010
Autorità per l'energia elettrica e il gas 2
AGENDA
• Overview on the electricity quality of service regulation
• Short overview on the electricity and gas smart metering regulation
QUALITY STANDARDS
(guaranteed/overall)and DIRECTIVESArt. 2(12) para. h)
AUTOMATIC COMPENSATIONS
IN CASE OF STANDARD NON-FULFILLMENT
Art. 2(12) para. g)
QUALITY-TARIFF LINK
Art. 2(19) para. a) Art. 2(12) para. e)
PROPOSALS FOR LICENSING
Art. 2(12) para. b) and o)
Regulatory Authority
(vs. licensing admin.)
(vs. customers)
SANCTIONS IN CASE OF MISRESPECT OF
REGULATORY ORDERS
Art. 2(20) para. c)
(vs. utilities)
LEGAL AND REGULATORY FRAMEWORK
Regulatory Authority’s legal powers
Autorità per l'energia elettrica e il gas 4
• The law foresees two types of quality standards– Guaranteed standards (GS): have the
function of ensuring that all consumers receive a minimum quality level and therefore are oriented to the protection of (worst-served) customers through compensations;
– Overall standards (OS): have the function to monitor the company performance at system level and therefore are oriented to promoting improvement through incentive/penalties schemes
• It’s up to the Authority to choose which type of standard apply to different quality issues
LEGAL AND REGULATORY FRAMEWORK
Guaranteed and overall standards
Autorità per l'energia elettrica e il gas 5
LEGAL AND REGULATORY FRAMEWORK
Guaranteed and overall standards• Guaranteed Standards
– referred to each single transaction between customer and utility– detailed knowledge of the company performance, down to individual
customer level (detailed measurements are needed)– Guaranteed standard = minimum quality
• CQ: maximum time to connect the customer with simple work• CS: maximum number of interruptions per year that affect the single customer
• Overall Standards – referred to the average performance of the utility in a given area– monitoring function through periodic publication of results (might
affect the reputation of the company, if not its financial results) – Overall standard = average quality (or quality at a given percentile)
• CQ: at least 90% of customer’s claims answered within the maximum time for substantial reply
• CS: maximum number of interruptions per year per customer (average in a given area)
Autorità per l'energia elettrica e il gas 6
SERVICE QUALITY REGULATION MEANS MULTIDIMENSIONAL OUTPUT
REGULATION
•VOLTAGE INVESTIGATIONS
•VOLTAGE VARIATIONS•VOLTAGE DIPS / SWELLS•RAPID VOLTAGE CHANGES
•FLICKER•HARMONICS•UNBALANCE
VOLTAGE QUALITY
COMMERCIAL QUALITY
•CALL CENTERS•BILLING•APPOINTMENTS•RICONNECTIONS AFTER NON-PAYMENT DISCONNECTIONS
•READING•COMPLAINTS •NEW SUPPLY ESTIMATES•CONNECTIONS TO NETWORK
•PROVIDING SUPPLY•METER INVESTIGATIONS
CONTINUITYOF SUPPLY
•UNPLANNED SUPPLY INTERRUPTIONS (LONG AND SHORT)
•PLANNED (NOTIFIED) SUPPLY INTERRUPTIONS
ELECTRICITYSERVICE
SU
PP
LY
GEN
ER
ATIO
N,
TR
AN
SM
ISS
ION
A
ND
DIS
TR
IBU
TIO
N
Autorità per l'energia elettrica e il gas 7
PROMOTE QUALITY
IMPROVEMENT
• SET AND MAINTAIN OVERALL QUALITY STANDARDS
• LINK QUALITY AND REVENUES (TARIFFS)
FAVOUR AND TEST MARKET MECHANISMS
• PREFER CUSTOMER CHOICE WHENEVER POSSIBLE AND SAFE
PROTECT WORST-SERVED
CUSTOMERS
• SET AND MAINTAIN GUARANTEED QUALITY STANDARDS
• DETERMINE INDIVIDUAL COMPENSATIONS FOR STANDARD MISMATCHING
MAKE INFORMATION
AVAILABLE
• SET RELIABLE MEASUREMENT RULES FOR QUALITY FACTORS
• PUBLISH ACTUAL QUALITY LEVELS
OBJECTIVES OF SERVICE QUALITY REGULATION
REGULATION OF QUALITY
PREREQUISITE
INCENTIVE QUALITY REGULATION (P.B.R.)
COMPETITION
Autorità per l'energia elettrica e il gas 8
A CONCEPTUAL MAP FOR SERVICE QUALITY REGULATION
Telephoneresponse incentives
Volt.Qual.Monitoring systems
Volt.Qual.minimum standards
VOLTAGE QUALITY
CONTINUITY OF SUPPLY
COMMERCIAL QUALITY
FAVOUR AND TEST MARKET MECHANISMS
PROMOTE QUALITY
IMPROVEMENT
PROTECT WORST-SERVED
CUSTOMERS
MAKE INFORMATION
AVAILABLE
Powerquality
contracts
Regulatorymeasurement guidance
Publicationactual quality levels
Multiple/Very long
interruption standards
Guaranteedquality
standards
Incentiveand penalty mechanism
Autorità per l'energia elettrica e il gas 9
MONITORING CONTINUITY OF SUPPLY
DISTRIBUTION
Telephoneresponse incentives
Volt.Qual.Monitoring systems
Volt.Qual.minimum standards
VOLTAGE QUALITY
CONTINUITY OF SUPPLY
COMMERCIAL QUALITY
FAVOUR AND TEST MARKET MECHANISMS
PROMOTE QUALITY
IMPROVEMENT
PROTECT WORST-SERVED
CUSTOMERS
MAKE INFORMATION
AVAILABLE
Powerquality
contracts
Regulatorymeasurement guidance
Publicationactual quality levels
Multiple/Very long
interruption standards
Guaranteedquality
standards
Incentiveand penalty mechanism
Autorità per l'energia elettrica e il gas 10
Regulatory measurement guidance:
Continuity of supply - basic concepts• Territorial classification of affected
customers
• LV customers involved in interruptions
• The telecontrol system
• The interruption register
• Force majeure
• How continuity is measured
• Who measures continuity
• Audits on continuity data
Autorità per l'energia elettrica e il gas 11
• A territorial classification is needed in order to set separate and acceptable standards
• Italian classification• Urban (“high density”) areas: territory of
municipalities with more than 50,000 inhabitants
• Sub-urban (“medium density”) areas: territory of municipalities with more than 5,000 and less than 50,000 inhabitants
• Rural (“low density”) areas: territory of municipalities with less than 5,000 inhabitants
TERRITORIAL CLASSIFICATION OF AFFECTED CUSTOMERS
Autorità per l'energia elettrica e il gas 12
LV CUSTOMERS INVOLVED IN INTERRUPT.• Interruptions due to faults at HV or MV level: Estimate of number of LV users involved =
MV/LV transf. involved * ratio of LV users per MV/LV transf.
(calculated separately for each district level)
• Interruptions due to faults at LV level: Estimate of number of LV users involved =
LV lines involved * ratio LV users per LV line (calculated separately for each district level)
Until 2007: estimation
As from 2008: actual number• Through information systems (e.g.: SCADA, GIS, etc.)
• Through smart metering systems (financial incentive; in this case the registration of the actual number of LV customers has been postponed to 2010)
Autorità per l'energia elettrica e il gas 13
THE TELECONTROL SYSTEM
• The Italian continuity of supply regulation sets a minimum requirement about telecontrol system (HV and LV level)
– Every event of opening and closure of breaker (at HV or MV level, >1 kV) must be automatically detected and recorded
– There must be an automatic printing of all events on the grid– The telecontrol system must be able to control at least the HV and
MV circuits at the terminals of each HV/MV, MV/MV transformer stations and MV switching stations or interconnection station with other DISCOs
• For faults on LV networks only manual registration is required but all the telephone calls must be reported in written in a separate register
– in order to verify that crews have been engaged after all telephone calls for repairing the fault
Autorità per l'energia elettrica e il gas 14
HV/MV station
HV/MV station
MV/LV substations
Example: telecontrol system in a network
Autorità per l'energia elettrica e il gas 15
Breakers that must be remotely controlled
HV/MV station
HV/MV station
MV/LV substations
Example: telecontrol system in a network
Autorità per l'energia elettrica e il gas 16
THE INTERRUPTION REGISTER
• For each interruption, the distribution company must record the following data in the “interruption register”
– Type of interruption (long/short/transient)– Starting time (see also telecontrol system)– Number of customer affected– Duration (for each group of customers with same duration)– Voltage level (T, HV, MV, LV)– Code of the affected circuits– Cause (force majeure, external damages, other)– Specific documentation if cause = F.M. or EXT.DAM.– Specific documentation if interruption notified
• At the end of the year, an electronic copy of the register in sent via e-mail to the regulatory authority
Autorità per l'energia elettrica e il gas 17
FORCE MAJEURESimplification process1. 1st Regulatory Period (2000-2003)
• Only documental evidence
2. 2nd Regulatory Period (2004-2007)
• Choice between documental evidence and statistical alghoritm (Major Event Days)
3. 3rd Regulatory Period (2008-2011)
• Only statistical alghoritm (Exceptional Condition Periods) + possibility of documental evidence for few specific cases
Autorità per l'energia elettrica e il gas 18
HOW CONTINUITY IS MEASURED
• Interruptions are described through– Time between events or number of interruptions
(for each type) in a period of time (in general, 1 year) and in a given distribution territory (homogenous!) of N customers
• SAIFI: average number of long interruptions per customer per year (MAIFI for short interr.)
• SAIDI: average duration of interruption per customer per year
– Per each interruption of the same type, main characteristics to be recorded are
• Customers affected (involved) Ni SAIFI, SAIDI
• Duration (time of start & finish) Di SAIDI
tot
K
ii
N
NSAIFI
1
tot
i
K
ii
N
DNSAIDI
1
Autorità per l'energia elettrica e il gas 19
WHO MEASURES CONTINUITY
• Distribution company– Remote control system (SCADA): allows automatic registration of
each interruptions starting time and each breaker operation• Italy: compulsory on each HV circuit and each MV circuit
– Interruption register: contain all data requested for each interruption (manually updated)
• Italy: compulsory for each long and short interruption; users can have access to the register
• Regulatory Authority– Is provided each year with yearly continuity indicators and
an electronic copy of the register and makes audits• Italy: per each territorial district (~300): SAIDI, SAIFI, MAIFI,
separately for: planned and unplanned interruption, causes of interruption, voltage quality level, territorial density
• Customers: individual information for major ones• Italy: customer can ask for individual measurement
Autorità per l'energia elettrica e il gas 20
EXAMPLE OF CONTINUITY YEARLY DATA PROVIDED TO THE AUTHORITY
(enforced from 1999)UTILITY: ENEL Distribuzione Spa
INTERRUPTIONS: UNPLANNED, LONG YEAR: 2004TERRITORY: ALL AGGREGATE UP TO MONTH: 12
CAUSE TRASM. HV MV LV TOTALDURATION (CML, SAIDI)
Acts of God0,0 0,0 14,9 1,1 16,0
Users' or third parties' respons. 2,3 0,1 11,2 1,5 15,0Utility's responsibility 0,0 3,0 45,6 14,4 63,1
Total all causes 2,3 3,1 71,7 17,0 94,1
CAUSE TRASM. HV MV LV TOTALNUMBER (CIs, SAIFI)
Acts of God0,00 0,00 0,08 0,00 0,09
Users' or third parties' respons. 0,14 0,01 0,28 0,01 0,44Utility's responsibility 0,00 0,10 1,87 0,14 2,11
Total all causes 0,14 0,11 2,23 0,15 2,64
VOLTAGE LEVELS
Autorità per l'energia elettrica e il gas 21
AUDITS ON CONTINUITY DATA Steps for audit evaluation
1. PlanningA. Choice of the telecontrol centre/districts to be auditedB. Preparation of “check-list”, according to specific situations
2. Formal decision– Regulatory order issued by the Authority and published in the
internet website without names of the selected companies
3. One week in advance: announcement– The Operator is informed about the documentation it has to make
ready and the date/place of the audit
4. During the audit:A. Filling the check-list regarding operator business administration,
procedures of interruptions management, telecontrol system …) B. Random sampling interruptions to be checkedC. Final minutes of the audit operation
5. After the audit:- Report of the audit cointaining calculation of 3 indexes
(accuracy, correctness, registration system), communicated to the company
– final deliberation for approving or rejecting (after formal contraddittorio) on the basis of indexes results
Autorità per l'energia elettrica e il gas 22
NO
AL
PV
MI
VACO BG
LC
TN
PD
PR
PG
FR
CE
IS
CB
AV
SA
PZ
ME
BN
MT
CS
LO
AQ
TE - B
UD
BS
CR
GR
TO
CNCN
AS
VB
VC
MN
PC
VT
MS
BI
PE
LE
TR
RO
LU
VI
VR
CH
BR
SO
DEVAL AO
IM
SP
GO
PN
TS
BZ
BL
RE
MOBO
FE
RA
FO
RN
SI
PT PO
FI
AR
PS
AN
MC
AP
LT
FG
BA
KR
CZ
VV
RC
SR- B
CT
CL
EN
TP
AG
Zecca Ortona
AMAIESan Remo
AMET Trani
ASM Bressanone
AGS Riva del Garda
AE-EWBolzano
AcegasTrieste
AIM Vicenza
AEM Cremona
ASM Rovereto
Sippic Capri
AMI Imola
Milano AEM
Torino AEM
Atena Vercelli
AGSM Verona
ASM Voghera
AMPS Seregno
APB Brunico
ASM Terni
CA
OR
SS
NU - M
AMPS Parma
ASM Brescia
META Modena
AUDITS BY AEEG ON CONTINUITY DATA
Legenda
NA - ANA - M
NA - B
RI
TV - ATV - BTV - M
VE - M
VE - A
VE - B
RG - MRG - A
RG - B
SR- A
SR- M
PA - BPA - M
PA - A
Cefalù non EnelCefalù Enel
SV GE - B
GE - M
TA - A TA - M
TA - B
GE - A
RM - A
RM - M
RM -B
Roma Acea
2000
PI
LI
TE - M
1998-99
2001
2002
2003
2004
2005
2006
NU - BNU - B
AUDITS ON CONTINUITY DATA
Autorità per l'energia elettrica e il gas 23
INCENTIVE REGULATIONDISTRIBUTION
Telephoneresponse incentives
Volt.Qual.Monitoring systems
Volt.Qual.minimum standards
VOLTAGE QUALITY
CONTINUITY OF SUPPLY
COMMERCIAL QUALITY
FAVOUR AND TEST MARKET MECHANISMS
PROMOTE QUALITY
IMPROVEMENT
PROTECT WORST-SERVED
CUSTOMERS
MAKE INFORMATION
AVAILABLE
Powerquality
contracts
Regulatorymeasurement guidance
Publicationactual quality levels
Multiple/Very long
interruption standards
Guaranteedquality
standards
Incentiveand penalty mechanism
SAIDI: as from 2000SAIFI+MAIFI: as from 2008
Autorità per l'energia elettrica e il gas 24
CONDITIONS FOR SUCCESSFUL SERVICE QUALITY REGULATION
1. Adjust regulatory scheme objectives to account for specific factors
2. Keep the scheme as simplest as possible in order to give companies right signals for investments
3. Quality regulation is never a permanent solution: periodic evaluation and revision
4. Quality regulation greatly benefits from a gradual approach to the implementation process
5. An open dialogue across all interested parties is a fundamental part of an efficient regulation
Autorità per l'energia elettrica e il gas 25
1. ADJUST REGULATORY SCHEME OBJECTIVES TO ACCOUNT FOR SPECIFIC FACTORS
• Gap between level of continuity in Italy and other major EU countries (FR, UK, DE) OBJECTIVE A: improve the Italian average level of
continuity towards European benchmarks
• Gaps between Northern and Southern regions OBJECTIVE B: reduce variation of regional and
district levels around the country average level
• Liberalisation and privatisation processes OBJECTIVE C: Increase network investments for
maintaining good levels (if achieved) or for improvement
OBJECTIVE D: Ensure customer satisfaction for electrical service
Autorità per l'energia elettrica e il gas 26
2. SCHEME AS SIMPLEST AS POSSIBLE /i
REGULATION (once every 4 years) SETTING STANDARDS FOR IMPROVEMENT AND SETTING REWARD/PENALTIES PARAMETERS
• Ex-ante for 4 years• Reference to long-term objectives• Improvement baseline• Reward/penalty parameters (based on WTP customer
survey)
IMPLEMENTATION AND CONTROL (every year)COMPARING ACTUAL LEVELS WITH STANDARDS AND APPLY FORMULA FOR ACTUAL REWARDS AND PENALTIES
• Each year t, companies are rewarded or penalised according to their performance
• Tariff is consequently adjusted
Autorità per l'energia elettrica e il gas 27
2. SCHEME AS SIMPLEST AS POSSIBLE /ii
REGULATION (once every 4 years) SETTING STANDARDS FOR IMPROVEMENT
• Ex-ante for 4 years• Reference to long-term objectives• For each district a given improvement is required year
by year (each company must improve % each year in each district)
t0 1 2 3 4 … … … 12
Stdt [CML-SAIDInet]
LivPart
LivObk
12
1
1
j
k
j LivPart
LivOb
j: Territ. District (1..300)k: Territ. Density (High/Medium/Low)t: year (regulatory period: 4 years)
)1(1,, jtjtj StdStd
Autorità per l'energia elettrica e il gas 28
2. SCHEME AS SIMPLEST AS POSSIBLE /iii
tqXRPIcapprice _
Actt [CML]
Qt [€]
Stdt
-Min
+Max
IMPLEMENTATION AND CONTROL (every year) COMPARING ACTUAL LEVELS WITH STANDARDS AND APPLY FORMULA FOR ACTUAL REWARDS AND PENALTIES
• Each year t, companies are rewarded or penalised according to their performance Actj,t (unitary reward/penalty parameters are set ex-ante at the beginning of the regulatory period)
• Tariff is adjusted yearly: ±qt = Qt /allow.revenues [%]
• Reward and penalties are capped
tj
Districtsj
tj
Districtsj
tjt VENSActStdQQ tj ,,, )( ,
Unitary incentive/penalty ex-ante [€/kWh-not-served]based on WTP/WTA survey
8760,,,,
,domtjdomndomtjndom
tjEncEncVENS
Autorità per l'energia elettrica e il gas 29
UNITARY INCENTIVE/PENALTY PARAMETERS used in the second regulatory period (2004-07)
DOMESTIC CUSTOMERS
Parameter Cdom
BUSINESS CUSTOMERS
Parameter Cndom
(BEST DISTRICTS) Below national ref. 7.2 €/kWh-ENS 14.4 €/kWh-ENS
(MEDIAN) From 1x to 3x nat.ref.
10.8 €/kWh-ENS 21.6 €/kWh-ENS
(WORST DISTRICTS) Above 3x national ref.
14.4 €/kWh-ENS 28.8 €/kWh-ENS national reference (SAIDI-net): urban 25 min/cust/year, rural 60 min/cust/year
For further details: Bertazzi, Fumagalli, Lo Schiavo, CIRED (2005) paper n. 300
2. SCHEME AS SIMPLEST AS POSSIBLE /iv
Autorità per l'energia elettrica e il gas 30
Reference standards
0
10
20
30
40
50
60
70
80
90
0 1 2 3 4 5 6 7 8 9
CU
ST
OM
ER
MIN
IUT
ES
LO
ST
(n
et o
f in
terr
up
tio
ns
no
t at
trib
uta
ble
to
dis
trib
uti
on
co
mp
anie
s)
TARGETS ACTUAL LEVELS
1998/99 1999/00 2000/01 2001/02 2002/03 2003/04 2004/05 2005/06 2006/07
1° REGULATORY PERIOD
2° REGULATORY PERIOD
REFERENCE STANDARDS
Referencestandards
0
10
20
30
40
50
60
70
80
90
0 1 2 3 4 5 6 7 8 9
CU
ST
OM
ER
MIN
IUT
ES
LO
ST
(n
et o
f in
terr
up
tio
ns
no
t at
trib
uta
ble
to
dis
trib
uti
on
co
mp
anie
s)
TARGETS ACTUAL LEVELS
1998/99 1999/00 2000/01 2001/02 2002/03 2003/04 2004/05 2005/06 2006/07
1° REGULATORY PERIOD
2° REGULATORY PERIOD
REFERENCE STANDARDS
Example: URBAN AREAS
Referencestandards
2. SCHEME AS SIMPLEST AS POSSIBLE /vINCENTIVE REGULATION ADJUSTMENT FROM 1ST TO 2ND REGULATORY PERIOD
Autorità per l'energia elettrica e il gas 31
SAIDI - 1998-2008 (excluded load shedding and big incidents on the Transmission network)
3. PERIODIC EVALUATION OF EFFECTS /i Objective A Improve overall continuity level for
Italy
131
9778 70 59 61 50 48 50
56
52
3735
32 19
11 10
40
0
20
40
60
80
100
120
140
160
180
200
1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008
Min
uti
per
si p
er c
lien
te a
ll'a
nn
o(e
sclu
si in
terv
enti
sist
emi d
i dife
sa e
inci
dent
i rile
vant
i RT
N)
Interruzioni di responsabilità del distributore Interruzioni non di responsabilità del distributore
AVERAGE EXTRA-PRICE FOR CUSTOMERS 2000-2003: ABOUT 3
€/CUSTOMER/YEAR2004-2007: ABOUT 4 €/CUSTOMER/YEAR
Interruptions due to DSOs responsibilities Interruptions out of DSOs responsibilities
Autorità per l'energia elettrica e il gas 32
3. PERIODIC EVALUATION OF EFFECTS /ii Objective A Improve overall continuity level for
ItalySAIDI - 1998-2008 (only interruptions due to DSOs responsibilities)
105
71
3628
37 324445
546672
8289
4844
64 67
5168
139
92
81
165166
787490
78
108
257
224
207
144
504850
6159
163
147
13197
7870
0
50
100
150
200
250
300
1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008
Min
uti
per
si p
er c
lien
te B
T a
ll'a
nn
oso
lo in
terr
uzio
ni d
i res
pons
abili
tà d
ell'i
mpr
esa
dist
ribu
tric
e
NORD CENTRO SUD ITALIA
Autorità per l'energia elettrica e il gas 33
3. PERIODIC EVALUATION OF EFFECTS /iii Objective A Improve overall continuity level for
ItalySAIFI - 1998-2008 (excluded load shedding and big incidents on the Transmission network)
1,50
1,23
1,69
1,45
1,82
2,46 2,522,38
2,151,95 1,90
2,13
1,862,15
2,472,48
4,434,76
2,79
3,07
3,74
2,59
3,48
3,643,473,73
3,41
4,07
4,985,164,97
5,51
3,86
2,372,162,292,422,48
2,772,76
3,293,59
3,813,91
0
1
2
3
4
5
6
1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008
Nu
me
ro m
ed
io d
i in
terr
uzi
on
i pe
r c
lien
te a
ll'a
nn
o(e
sclu
si in
terv
en
ti si
ste
mi d
i dife
sa)
NORD CENTRO SUD ITALIA
Autorità per l'energia elettrica e il gas 34
3. PERIODIC EVALUATION OF EFFECTS /ivObjective B Close the gaps between North and
SouthSAIDI - 1998-2008 (excluded load shedding and big incidents on the Transmission network)
31
7766
156
117 123
90
5242
88106
129 135
9686 74
5359
83
194204
102116
180
8986
988798
242
262270
285
162
586180
105115
149
187192
186
91
0
50
100
150
200
250
300
1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008
Min
uti
per
si p
er c
lien
te a
ll'a
nn
o
(esc
lusi
inte
rve
nti
sist
em
i di d
ifesa
e in
cid
en
ti ri
leva
nti
RT
N)
NORD CENTRO SUD ITALIA
Autorità per l'energia elettrica e il gas 35
3. PERIODIC EVALUATION OF EFFECTS /v
Objective C Improve network investmentsMillions Euro
2000
420
2001
533
2002
562
»CAGR »16%
263 292
159 19675
8280
82
Media ‘98/’99
386
386
286
High density (urban)
»CAGR »16%
+16%per year
Medium density (sub-urban)
Low density (rural)
Millions Euro
2000
420
2001
533
2002
562
»CAGR »16%
»CAGR »16%
263 292
159 19675
8280
82
Media ‘98/’99
386
386
286
High density (urban)
»CAGR »16%
+16%per year
Medium density (sub-urban)
Low density (rural)
Year 2004
2005
2006
2007
Net incentives [M€] (incentive-penalties)
67 125 165 189
Impact upon tariffs
2nd regulatory period 4.0 €/cust/yearqavg 04-07 +3.5%
Investments for quality (dedicated)
source: Enel response to AEEG consultation paper
(2003)
Effects of regulatory incentive scheme for continuity of supply
Autorità per l'energia elettrica e il gas 36
CORRELATION BETWEEN ACTUAL QUALITY LEVELS AND CUSTOMER SATISFACTION
(each point is a single Italian Region)
R2 = 0,8727
R2 = 0,8758
0
5
10
15
20
25
30
0 1 2 3 4 5 6 7 8 9 10 11 12INTERRUPTIONS PER CUSTOMERS (NUMBERS)
UN
SA
TIS
FIE
D C
US
TO
ME
RS
(%
)
1998
2002
3. PERIODIC EVALUATION OF EFFECTS /vi
Objective D Ensure customer satisfaction
Autorità per l'energia elettrica e il gas 37
1st period 2nd period 3rd periodSAIDI – CMLs (avg. Duration)
Incentives / penalties
Incentives / penalties
Incentives / penalties
Multiple interr. (max numb., MV)
Monitoringnumb. interr.
(per single MT cust.)
Guaranteed standard
(only long interr.)
Stricter guarant’d standard
(only long interr.)
SAIFI – CIs (avg. Number)
Monitoring num. long int.
Monitoring num. both long
& short
Incent./penalties
(SAIFI+MAIFI)
Very long interr.(max durat,LV-MV)
Consultation and statistic
research
Guarant’d stds (incl.except.events)
Quality of Transm. Service
Monitoring transmission
Incent./penalties
transm. (ENS)
Voltage quality
Monitoring VQ on HV-MV networks
Research ShortCirc.Power
Revision of CLC EN 50160
Multiple interr. (max numb., LV)
Connectivity model for LV
Monitoring num. both long & short (per single
LV cust.)
4. GRADUAL APPROACH: EVOLUTION
Autorità per l'energia elettrica e il gas 38
1.1st
CONSULTAT.PAPER
Jun-03
2.PUBLIC
HEARINGS
Jul-03
3.2nd
CONSULTAT.PAPER
Nov-03
4.3rd
CONSULTAT.PAPER
Jan-04
5.PUBLIC
HEARINGS
Jan-04
D. 4/04 QUALITY
CODE2004-07
Jan-04
• Quantitative assessment of effects of 1st regulatory period
• Objectives for 2nd regulatory period
• Alternatives• Views invited
on issues
• Draft legal text (“ordinance”)
• Further alternatives taking into account comments
• Range of values for main parameters
• Stressed objective of convergence
• Further alternatives taking into account comments
• Range of values for main parameters
• Includes both continuity and service quality
• Technical report with first impact analysis
5. OPEN DIALOGUE: MULTIPLE CONSULTATION
From 2007: RIA (Regulatory Impact Assessment)
Autorità per l'energia elettrica e il gas 39
EUROPE, DURATION OF INTERRUPTIONS(EXCEPTIONAL EVENTS ARE EXCLUDED)
0
100
200
300
400
500
1999 2000 2001 2002 2003 2004 2005 2006 2007
Min
ute
s lo
st
pe
r c
us
tom
er
Austria HV, MVDenmark HV, MVEstonia HV, MV, LVFrance LVGermany HV, MV, LVIceland HV, MV, LVItaly HV, MV, LVLithuania HV, MV, LVPortugal HV, MV, LVSpain HV, MV, LVUK HV, MV, LV
Source: CEER, 4th Benchmarking Report, 2008.
Autorità per l'energia elettrica e il gas 40Fonte: CEER, 4th Benchmarking Report, 2008.
0
1
2
3
4
5
6
1999 2000 2001 2002 2003 2004 2005 2006 2007
Inte
rru
pti
on
s p
er c
ust
om
er
Austria HV, MV
Denmark HV, MV
Estonia HV, MV, LV
France LV
Germany HV, MV, LV
Iceland HV, MV, LV
Italy HV, MV, LV
Lithuania HV, MV, LV
Portugal HV, MV, LV
Spain HV, MV, LV
UK HV, MV, LV
EUROPE, NUMBER OF LONG INTERRUPTIONS(EXCEPTIONAL EVENTS ARE EXCLUDED)
Autorità per l'energia elettrica e il gas 41
GUARANTEED STANDARDSDISTRIBUTION
Telephoneresponse incentives
Volt.Qual.Monitoring systems
Volt.Qual.minimum standards
VOLTAGE QUALITY
CONTINUITY OF SUPPLY
COMMERCIAL QUALITY
FAVOUR AND TEST MARKET MECHANISMS
PROMOTE QUALITY
IMPROVEMENT
PROTECT WORST-SERVED
CUSTOMERS
MAKE INFORMATION
AVAILABLE
Powerquality
contracts
Regulatorymeasurement guidance
Publicationactual quality levels
Multiple/Very long
interruption standard
Guaranteedquality
standards
Incentiveand penalty mechanism
Autorità per l'energia elettrica e il gas 42
MULTIPLE INTERRUPTIONS /I• For MV customers• Maximum number of long interruptions in a solar year are
concerned• Guaranteed stds:
• MV customers have right to automatic compensations if their plants/protection relays guarantee selectivity with protection relays of the DNO (through written declaration to the DNO, according to DNO’s specifications – exemption for new customer plants)
• MV customers who do not send the declaration to the DNO pay an extra tariff component
• Interruptions due to FM and third party damages are excluded• Upstream interconnected DNOs (or TSO) must contribute to
automatic compensations to customers proportionally to the number of long interruptions of their responsibilities that involve downstream interconnected DNOs
Urban Sub-urban
Rural
Until 2009
3 long int./year
4 5
From 2010
2 3 4
Autorità per l'energia elettrica e il gas 43
MULTIPLE INTERRUPTIONS /IIWorst served customers
% clienti MT peggio serviti su totale clienti
0,0%
5,0%
10,0%
15,0%
20,0%
25,0%
30,0%
35,0%
Pie
mon
teLo
mba
rdia
Tren
tino
Alto
Adi
geV
enet
o
Friu
li Ve
nezi
a G
iulia
Ligu
riaE
mili
a R
omag
naTo
scan
aU
mbr
iaM
arch
e
Lazi
oA
bruz
zoM
olis
eC
ampa
nia
Pug
liaB
asili
cata
Cal
abria
Sic
ilia
Sar
degn
a
Nor
dC
entr
o
Sud
ITA
LIA
2006
2007
2008
• Distribution by Italian region (2006-2008)
Autorità per l'energia elettrica e il gas 44
MULTIPLE LONG INTERRUPTIONS Standards in force in Europe
Territorial classificati
on
Country
Metro-politan
Urban (cities)
Semi-urban (towns)
Rural (village
s)
Rural dispers
e
FRANCE 2 (MV)
n.a (LV)
3 (MV)
n.a (LV)
3 (MV)
n.a (LV)
6 (MV)
n.a (LV)
GREAT BRITAIN
3 (MV) (each longer than 3 hours)
3 (LV) (each longer than 3 hours)
ITALY3 (MV, 2 from 2010)
n.a (LV)
4 (MV, 3 from 2010)
n.a (LV)
5 (MV, 4 from 2010)
n.a (LV)
PORTUGAL
8 (MV)
12 (LV)
18 (MV)
23 (LV)
30 (MV)
36 (LV)
SPAIN8 (MV)
12 (LV)
12 (MV)
15 (LV)
15 (MV)
18 (LV)
20 (MV)
24 (LV)
Source: CEER, 3rd Benchmarking Report on Electricity Quality of Supply, 2005. Updates for Spain and Italy
Autorità per l'energia elettrica e il gas 45
VERY LONG INTERRUPTIONS /IStandards
– Guaranteed standards are applicable to both normal and exceptional events
– Statistical method for identifying “Exceptional Condition periods” (can be integrated with documental evidence for few specific cases)
– Suspension of clock for safety issues– Company must pay guaranteed standards– In case of major or exceptional events, companies are compensated through a
dedicated fund– All customers put a little money in the fund – Companies are incentivised in order to improve their performance in “normal
conditions”• Companies must put money in the Fund according to their actual quality net of major and
exceptional events• Companies receive a sum that is proportional to the expected quality (decreasing over time)
Type of interruption
Territorial classification
Standard for LV customers
Standard for MV customers
Unplanned • Urban• Sub-urban • Rural
8h12h16h
4h6h8h
Planned All 8h 8h
Autorità per l'energia elettrica e il gas 46
VERY LONG INTERRUPTIONS /IIAutomatic reimbursements
Household customers
LV and MV consumers with power <= 100kW (excluded households)
Non household LV consumers with power > 100kW
Non household MV consumers with power > 100kW
Standard not fulfilled
30€ 150€ 2€/kW 1,5€/kW
For each further period
15€
every 4 hours
75€
every 4 hours
1€/kW
every 4 hours
0,75€/kW
every 2 hours
Cap 300€ 1,000€ 3,000€ 6,000€
Autorità per l'energia elettrica e il gas 47
VERY LONG INTERRUPTIONS /III
• 2003: Blackout for transmission/dispatching problems (lost interconnections with abroad during night)– 33M customers affected (only Sardinia at safe), up to 24 hours
(Sicily)
• 2004: Large interruptions in some regions due to exceptional severe weather. – More than 2 M customers involved in 4 large events (7 regions); – Around 400.00 customers interrupted for more than 12 hours – Around 50.000 cust. for more than 2 days (up to 5 days, 2.000 cust.)
• 2005: First round of consultation• 2006: Second round of consultation• 2007: Third round of consultation and final decision (July)• 2008: Implementation time• 2009 1st July new standards for all MV-LV customers in case
of very long interruptions with automatic compensations
Autorità per l'energia elettrica e il gas 48
Territorial classificatio
n
Country
Urban (cities) Semi-urban (towns)
Rural (villages)
FRANCE 6 h (MV and LV, exceptional events are excluded)
GREAT BRITAIN
18 h (MV and LV, normal conditions, transmission is excluded)
from 24 h to 100 h (exceptional events, depending on the severity)
ITALY4 h (MV from 2009)
8 h (LV from 2009)all events
6 h (MV from 2009)
12 h (LV from 2009) all events
8 h (MV from 2009)
16 h (LV from 2009)
all events
SWEDEN 12 h (MV and LV, (events out of the control of the DSO and big blackouts are excluded)
IRLAND24 h (MV and e LV,
(exceptional events and events on the transmission network are excluded)
VERY LONG INTERRUPTIONS Standards in force in Europe
Source: CEER, 3rd Benchmarking Report on Electricity Quality of Supply, 2005. Updates for Spain and Italy
Autorità per l'energia elettrica e il gas 49
COMMERCIAL QUALITYDISTRIBUTION
Telephoneresponse incentives
Volt.Qual.Monitoring systems
Volt.Qual.minimum standards
VOLTAGE QUALITY
CONTINUITY OF SUPPLY
COMMERCIAL QUALITY
FAVOUR AND TEST MARKET MECHANISMS
PROMOTE QUALITY
IMPROVEMENT
PROTECT WORST-SERVED
CUSTOMERS
MAKE INFORMATION
AVAILABLE
Powerquality
contracts
Regulatorymeasurement guidance
Publicationactual quality levels
Multiple/Very long
interruption standard
Guaranteedquality
standards
Incentiveand penalty mechanism
Autorità per l'energia elettrica e il gas 50
GUARANTEED STANDARDS (2004-2007)
Final LV customer
s
Final MV customer
s
Distrib.
Maximum time for estimating charges for execution of work on LV network
20 work.days
n.a.
Maximum time for execution of simple work
15 work.days
30 work.days
Maximum time for activation of supply
5
work.days
5 work.days
Maximum time for closing supply at customer’s request
5 work.days
7 work.days
Maximum time for restarting supply following suspension for lack of payment
1 day incl. Saturday
Maximum time band for customised appointments
3 hours
Maximum time for restoration of supply following a failure of the metering device
3 hours (day-time)4 hours (night-time)
2008-2011
Meter verification upon request of the customer
Voltage verification upon request of the customer
15 work.days
30 work.days
Autorità per l'energia elettrica e il gas 51
SERVICE QUALITY REGULATIONcomparison between before and
after Authority’s regulation
20001997 II° sem.
6.099 4.167 8.418 7.902 25.650 61.881 67.344 57.424 64.696 73.867
21 54 22 4.771 12.437 52.229 79.072 48.305 63.822 73.714
0,001 0,002 0,001 0,22 0,82 3,11 4,21 3,41 4,43 4,07
Total amount Actually paid For compensationsEuro Millions
Number of requestswith not fulfilledguaranteed standards
Actually paid Compensationpayments
Self-regulation Regulation issued by the Authority
1998 1999 2001 2002 20052003 2004 2006
Autorità per l'energia elettrica e il gas 52
SERVICE QUALITY REGULATIONEffects of guaranteed standards
(2006)
w.d.: working days
Number ofautomatic compensat.
ESTIMATE CHARGES (for work on the LV network) 20 working days 328.637 2,8% 13,08 8.434
COMPLETE SIMPLE WORKS (net of authorization) 15 working days 419.042 2,4% 8,77 9.688
START THE SUPPLY 5 working days 1.702.260 1,0% 1,97 16.653
TERMINTE THE SUPPLY (on customer’s request)5 working days
826.458 0,5% 1,58 3.144
RESTART AFTER NON-PAYMENT DISCONNECTION1 days
863.530 3,6% 0,51 32.361
CORRECT BILLING PROBLEMS (already paid sums)90 days
11.453 7,1% 46,65 515
SOLVING METERING FAULTS (with service interruptions)3 hours (daytime)
4 hours (night) 130.461 1,7% 1,71 2.501
KEEPING APPOINTMENTS (punctuality band hours) 3 hours 52.674 0,7% 259
SERVICES SUBJECT TO GUARANTEED STANDARDS
Standard
Number of requestsper year
% Stds not
fulfilled
Average Time (net)
w.d.
2006 RESULTS
Autorità per l'energia elettrica e il gas 53
AUTOMATIC COMPENSATIONSAmounts and exemptions
•Exemptions
– Force majeure and third party action (to be adequately proven)
– In cases where the customer is not up to date with payments owed to the operator.
– Concerning “maximum time for restoration of supply following a failure of the metering device “ the operator shall not be required to pay the compensation if the interruption of supply is caused:
• by release of lock cable terminals;• by intervention of the load limiter due to overconsumption;• by damages caused to the metering device when installed
in rooms where only the customer can have admittance.
• Amounts Domestic LV
customers
Non domestic
LV customers
MV customers
Automatic compensation (AC) paid in the next bill
30 euro 60 euro 120 euro
Autorità per l'energia elettrica e il gas 54
AUTOMATIC COMPENSATIONEscalation in case of delayed
execution
3*AC
days0=Rqst S=Std
EurosAC= automaticcompensation
Automatic compensation
to be paid within 90 days (from A)
Date (or hour) A when the service is actually done by the operator is beyond standard S
A=Act
AC
2*S
2*AC
3*SA=Act A=Act
Autorità per l'energia elettrica e il gas 55
OVERALL STANDARDSDISTRIBUTION (2008-2011)
Service LV customers MV customers
Minimum percentage of requests for the estimation of charges for the execution of works on the MV network made available within 40 working days
Non applicable 90%
Minimum percentage of requests of execution of complex works carried out within 60 working days
85% 90%
Minimum percentage of answers to complaints or requests of written information, made available within 20 working days
90% 95%
Autorità per l'energia elettrica e il gas 56
INFORMATION TO CUSTOMER
Telephoneresponse incentives
Volt.Qual.Monitoring systems
Volt.Qual.minimum standards
VOLTAGE QUALITY
CONTINUITY OF SUPPLY
COMMERCIAL QUALITY
FAVOUR AND TEST MARKET MECHANISMS
PROMOTE QUALITY
IMPROVEMENT
PROTECT WORST-SERVED
CUSTOMERS
MAKE INFORMATION
AVAILABLE
Powerquality
contracts
Regulatorymeasurement guidance
Publicationactual quality levels
Multiple/Very long
interruption standard
Guaranteedquality
standards
Incentiveand penalty mechanism
Autorità per l'energia elettrica e il gas 57
CUSTOMER INFORMATION
• Guaranteed Standards and automatic compensations need to be adequately communicated to the customers– At the request the customer is informed of his right to receive
compensations (for commercial quality)– If the standard is not fulfilled, the customer receive compensation
through the bill with a given message– Customers can claim for further damages if they are able to prove
it (ordinary jurisdiction, long times and difficulty to prove)
• Further communication tools:– Publication of data on the internet website of the Authority– “Interruption bill” for each MV customer, once per year (end-June)– Campaign for convincing MV customers to invest in improving
their installations and obtain the benefits of multiple interruption regulation
– Investigations in case of large events and publication of results (for instance for 2003 blackout)
Autorità per l'energia elettrica e il gas 58
Type of standard
guaranteedService
Execution of simple works (*)
Territory
Italy
Autorità per l'energia elettrica e il gas 59
Indicator Selected
CML
Territory Selected
Italy
Type of interruptions selected
Long unplanned
Responsibilities selected
All (overall CML, net of blackout and load shedding)
Autorità per l'energia elettrica e il gas 60
INCENTIVE REGULATION TRANSMISSION
Telephoneresponse incentives
Volt.Qual.Monitoring systems
Volt.Qual.minimum standards
VOLTAGE QUALITY
CONTINUITY OF SUPPLY
COMMERCIAL QUALITY
FAVOUR AND TEST MARKET MECHANISMS
PROMOTE QUALITY
IMPROVEMENT
PROTECT WORST-SERVED
CUSTOMERS
MAKE INFORMATION
AVAILABLE
Powerquality
contracts
Regulatorymeasurement guidance
Publicationactual quality levels
Multiple/Very long
interruption standard
Guaranteedquality
standards
Incentiveand penalty mechanism
Autorità per l'energia elettrica e il gas 61
BACKGROUND MONITORING OF TRANSMISSION CONTINUITY (1)
• Three years before the transmission continuity regulation, Regulatory Order 250/04 about the preparation of Grid Code was issued by AEEG:– Obligation TSO to register long (> 3 minutes),
short and transient (< 1 second) interruptions– Classification of interruptions: origin + cause +
list of curtailed users + grid status at time=0 + data per each interrupted user (start time, finish time, load shedding)
– Definition of continuity indicators and calculation methods: ENS, AIT, SAIFI (long interruptions), MAIFI (short) and energy not retired
– …
Autorità per l'energia elettrica e il gas 62
BACKGROUND MONITORING OF TRANSMISSION CONTINUITY (2)
– … (cont’d)– Monitoring of voltage quality parameters:
supply voltage variations, rapid voltage changes, voltage dips, overvoltages, flicker, harmonic distortion, voltage unbalance, frequency deviations
– Commitment of the TSO on expected quality levels for transmission service (proposed by TSO itself for regulatory approval), referred to continuity indicators
– Publication of a TSO yearly report describing actual performance vs. expected levels, and actions and plans for improvement of continuity indicators
– Reporting by TSO to Authority on transmission major incidents (ENS > 150 MWh, > 30 minutes)
Autorità per l'energia elettrica e il gas 63
BACKGROUND MONITORING OF TRANSMISSION CONTINUITY (3)
• The provisional approach of 250/04 provided for:– Transparency on quality issues– Reputational incentive to the TSO– Robust continuity measurement rules and dataTransmission Average Interruption Time in Italy and its territorial areas 2006-2008
0,0
0,5
1,0
1,5
2,0
2,5
3,0
3,5
Torino Milano Venezia Firenze Roma Napoli Palermo Cagliari All Italy
AIT
(sy
stem
min
ute
s/ye
ar)
Expected 2006 Expected 2007 Actual 2006 Actual 2007 Actual 2008
Data by Terna and AEEG
Autorità per l'energia elettrica e il gas 64
Transmission investments in Italy (1963-2008)
0
100
200
300
400
500
600
700
800
1960 1965 1970 1975 1980 1985 1990 1995 2000 2005 2010
Year
Inve
stm
ents
[M
€, m
on
ey 2
008]
Enel Enel T.E.R.NA. Terna
ITALIAN INCENTIVE REGULATION OF TRANSMISSION CONTINUITY:
OBJECTIVES• Reduction of ordinary outages
• Prevention and mitigation of major incidents
• Implicit objective: provide signals for investments justified by quality and security reasons to avoid the risk of solely market-based investments exclusively targeted to reduction of congestion
Transmission investments 1963-2008 Source: own
elaboration of public data
Autorità per l'energia elettrica e il gas 65
ITALIAN INCENTIVE REGULATION OF TRANSMISSION CONTINUITY:
INDICATORS• Three indicators (energy not supplied, number of
interruptions per user and number of users without interruptions)
• R-ENS, Regulated Energy Not Supplied• NIU, Number of Interruptions per grid User• UZI, number of grid Users with Zero Interruptions
• Regulation in force as from 2008.• Set improvement standards and reward/penalties
parameters for 2008-2011.• Economic effects only for 2010 and 2011
Autorità per l'energia elettrica e il gas 66
Smoothing and limitation function adopted to define R-ENS starting from ENS
250 2250 40000
0
125
250
375
500
625
750
875
1000
100 1000 10000 100000
Energy Not Supplied [MWh]
Reg
ula
ted
En
ergy
Not
Su
pp
lied
[M
Wh
]
Log scale
• R-ENS is expressed in MWh and based upon ENS
• A limitation function is adopted in order to deal both with transmission major incidents (with large ENS) and small-size ordinary outages
REGULATION OF TRANSMISSION CONTINUITY: CHOICE OF INDICATORS (1)
Source: own elaboration
Autorità per l'energia elettrica e il gas 67
• NIU includes short and long interruptions for all users directly connection to the national transmission grid
• NIU = SAIFI + MAIFI• NIU is calculated for each of the 8 territorial
areas, in which grid operation is organized• Unsymmetrical scheme (more penalties
than rewards) tailored to the objective of promoting uniformity of quality of transmission service across Italy
REGULATION OF TRANSMISSION CONTINUITY: CHOICE OF INDICATORS (2)
Autorità per l'energia elettrica e il gas 68
• UZI is number of grid Users with 0 interruptions per year, referred to the total number of users
• UZI has a reward-only structure, increasing the rewards for R-ENS and for NIU (in case of over-performance with respect to targets)
• UZI nature genuinely expresses the nature of transmission service: no grid users have to suffer interruptions due to transmission failures
REGULATION OF TRANSMISSION CONTINUITY: CHOICE OF INDICATORS (3)
Autorità per l'energia elettrica e il gas 69
• Automatic intervention of under-frequency load shedding schemes as a consequence of disturbances originated in the neighbouring interconnected countries;
• Preventive load shedding (communicated at least one day in advance adopting defined procedures) as a consequence of expected lack of generation adequacy;
• Forced line outages due to public orders (e.g. in case of fire when switching off the HV circuits is demanded by police or fire corps);
• Extreme disaster situations (e.g. earthquakes);• Intentional damages (e.g. terrorist attacks);• Extremely large black-outs (above 40000 MWh/event)
• Outages originated by users and outside NTG (NIU, UZI)
REGULATION OF TRANSMISSION CONTINUITY: EXCLUSION CAUSES
Autorità per l'energia elettrica e il gas 70
VOLTAGE QUALITY MONITORINGDISTRIBUTION AND TRANSMISSION
Telephoneresponse incentives
Volt.Qual.Monitoring systems
Volt.Qual.minimum standards
VOLTAGE QUALITY
CONTINUITY OF SUPPLY
COMMERCIAL QUALITY
FAVOUR AND TEST MARKET MECHANISMS
PROMOTE QUALITY
IMPROVEMENT
PROTECT WORST-SERVED
CUSTOMERS
MAKE INFORMATION
AVAILABLE
Powerquality
contracts
Regulatorymeasurement guidance
Publicationactual quality levels
Multiple/Very long
interruption standard
Guaranteedquality
standards
Incentiveand penalty mechanism
Autorità per l'energia elettrica e il gas 71
MONITORING UNITS INSTALLED ON MV BUS-BARS OF HV/MV SUBSTATIONS
400 monitoring units(they monitor about 10% of the MV bus-bars of the MV distribution network).
The sample is representative of the network characteristics in terms of:
• number of HV/MV substations in each region
• length of the MV lines• type of MV lines: cable, overhead,
mixed• neutral compensation or isolated
neutral• number of MV customers• density of LV customers
Autorità per l'energia elettrica e il gas 72
73 owned by as many MV customers who decided to voluntarily (with the promotion of the Authority) participate to the monitoring campaign
124 owned by Distribution Network Operators
This sample of units is not statistically representative of the monitored MV network
MONITORING UNITS INSTALLED ON MV DELIVERY POINTS
Autorità per l'energia elettrica e il gas 73
AVERAGE NUMBER OF DIPS ACCORDING TO THE NEW
prEN50160 /IItaly, Year 2007, all types of MV networks, MV bus-bars of HV/MV substations
Yellow cells: equipment immunity class 2Yellow+ Green: equipment immunity class 3Red line: compatibility curve
http://queen.ricercadisistema.it
Autorità per l'energia elettrica e il gas 74
0
50
100
150
200
250
300
Emilia
R.
Lom
bard
ia
Tosc
ana
Tren
tino
A.A.
Vene
to
Piemon
te
March
e
Sarde
gna
Friu
li V.G
.
Ligu
ria
Molise
Lazio
Puglia
ITALY
(avg
)
Abruz
zo
Sicilia
Campa
nia
Calabr
ia
Yea
rly
nu
mb
er o
f d
ips
per
po
int
AVERAGE NUMBER OF DIPS ACCORDING TO THE NEW
prEN50160 /IIItaly, Year 2007, all Regions, all types of MV networks, MV bus-bars of HV/MV substations
Autorità per l'energia elettrica e il gas 75
VOLTAGE QUALITY MONITORING ON TRANSMISSION AND HV DISTRIBUTION
NETWORKS (1/3)
Voltage level TransmissionHV
DistributionTotal
380 kV 7 0 7
220 kV 10 6 16
150 kV 23 23 46
132 kV 67 27 94
60 kV 0 2 2
Total 107 58 165
Number of installed measurement devices
Source: Terna and Ceer 4th Benchmarking Report, 2008
Autorità per l'energia elettrica e il gas 76
Number of dips per measurement point on 380kV and 220kV networks, year 2007.
Source: Terna and Ceer 4th Benchmarking Report, 2008
Residual voltage u
Duration t (ms)
(%)20 < t ≤ 100
100 < t ≤
500
500 < t ≤
1000
1000 < t ≤ 3000
3000 < t ≤
60000Total
90 > u ≥ 85 19.0 1.5 0.1 0.0 0.0 20.6
85 > u ≥ 70 24.2 3.5 0.3 0.0 0.0 28.0
70 > u ≥ 30 13.6 2.4 0.6 0.1 0.0 16.7
30 > u ≥ 10 0.5 0.3 0.0 0.0 0.1 0.9
10 > u 1.8 0.5 0.1 0.0 0.0 2.4
Total 59.1 8.2 1.1 0.1 0.1 68.6
VOLTAGE QUALITY MONITORING ON TRANSMISSION AND HV DISTRIBUTION
NETWORKS (2/3)
Autorità per l'energia elettrica e il gas 77
Number of dips per measurement point on 150kV and 132kV networks, year 2007.
Source: Terna and Ceer 4th Benchmarking Report, 2008
Residual voltage u
Duration t (ms)
(%)20 < t ≤ 100
100 < t ≤
500
500 < t ≤
1000
1000 < t ≤ 3000
3000 < t ≤
60000Total
90 > u ≥ 85 25.5 6.9 0.9 0.4 0.1 33.8
85 > u ≥ 70 24.4 6.3 0.6 0.2 0.0 31.5
70 > u ≥ 30 12.6 4.7 0.3 0.2 0.0 17.8
30 > u ≥ 10 1.1 0.9 0.1 0.1 0.1 2.3
10 > u 1.9 0.6 0.1 0.0 0.1 2.7
Total 59.1 19.4 2.0 0.9 0.3 88.1
VOLTAGE QUALITY MONITORING ON TRANSMISSION AND HV DISTRIBUTION
NETWORKS (3/3)
Autorità per l'energia elettrica e il gas 78
COMMERCIAL QUALITYSUPPLY
Telephoneresponse incentives
Volt.Qual.Monitoring systems
Volt.Qual.minimum standards
VOLTAGE QUALITY
CONTINUITY OF SUPPLY
COMMERCIAL QUALITY
FAVOUR AND TEST MARKET MECHANISMS
PROMOTE QUALITY
IMPROVEMENT
PROTECT WORST-SERVED
CUSTOMERS
MAKE INFORMATION
AVAILABLE
Powerquality
contracts
Regulatorymeasurement guidance
Publicationactual quality levels
Multiple/Very long
interruption standard
Guaranteedquality
standards
Incentiveand penalty mechanism
Autorità per l'energia elettrica e il gas 79
COMMERCIAL QUALITY REGULATION IN ITALY NEW GUARANTEED STANDARDS FOR SUPPLY ELECTRICITY & GAS (FROM 2009)
• MAXIMUM WAITING TIMES (All standards are in solar days)
- Appropriate response to a complaint 40- Invoice amendment 90– Invoice amendment for multiple invoice 20
• When guaranteed standards are not met by fault of the utility, users are entitled to receive automatic compensation payments through their bills
• Level of compensation payments are related to the type of user involved:
– domestic, business, industry: 20€– escalation like for commercial quality for distribution
• Users can always appeal to the court if damage is over the compensation payment
Autorità per l'energia elettrica e il gas 80
COMMERCIAL QUALITY REGULATION IN ITALY NEW OVERALL STANDARDS FOR
SUPPLY ELECTRICITY & GAS (FROM 2009)
- Answers to written requests of invoice amendment:- 40 solar days in 95% of cases
- Answers to written requests of information:- 30 solar days in 95% of cases
Autorità per l'energia elettrica e il gas 81
COMPLAINTS HANDLINGOne of the functions assigned by the institutional Law 481/99 is to assess complaints, appeals and reports from users or consumers, individually or as a body, as to respect for standards of quality and tariffs by the service operators
The Authority has a specific Department in charge for information and customer protection, having mainly the following tasks:• to set rules for protecting customers (about contracts conditions, billing transparency, pre-contractual information and so on)• to ensure transparency and information, having care for the relationships with Consumers’ Organizations• handling consumers’ complaints
Autorità per l'energia elettrica e il gas 82
COMPLAINTS HANDLING EVOLUTIONHow many complaints?
Main reasons for complaining (ex.: apr. 07-may 08)• Billing 33%• Contracts 19%• Pre-contractual information/misselling 15%• Disconnection for non-payment 9%• Quality of service (outages, connections, volt. quality) 9%• Consumption (estimate consumption, meter reading) 2,6%
1999 2002 2005 2008
Complaints received
213 449 1049 8000
People in information and Consumers Affaire Dep.
4 5 6 7
Autorità per l'energia elettrica e il gas 83
THE NEW CONSUMERS’ HELPDESK• The increasing number of complaints and the need for an
effective and satisfactory answer suggested to start, in 2007, the project for an externalization of complaints handling, giving the responsibility for the first stage to another public subject
• The consumers’ helpdesk has the task to develop all the activities that can be considered in preparation of a proceedings:– Receives complaints and appeals from the consumers and creates a file
for each complaint– Asks for information and clarifications to the suppliers– Suggests to the customers and to the suppliers the measure to adopt in
order to solve the problems raised– When the problem cannot be solved, or the consumer isn’t satisfied about
the answer transfers the file to the Authority for the final evaluation– Reports to the Authority about the complaints received and the activity
carried out
Autorità per l'energia elettrica e il gas 84
ONLY ONE INTERFACE FOR THE CONSUMER: THE SUPPLIER
•There is a timeliness obligation in force for Suppliers: 2 working days for sending the request of the final consumer to the Distributor and 2 working days for sending the answer of the Distributor to the final consumer
•Currently there aren’t any automatic compensations if the Supplier does not meet the above timeliness.
Autorità per l'energia elettrica e il gas 85
REGULATION OF CALL CENTERS
– Minimum requirements: opening time of Call Centers with human operator; information through the bill and internet web site
– Standard: measured on monthly base
• Access to the service AS 80%• Average waiting time TMA 240 sec.• Service level LS 90%
– Customer satisfaction: six month base survey on satisfaction of final customer who called the call center (through the call back methodology)
– Benchmarking score: published on six month base – three sub scores:
• PA depending on the accessibility to the service
• PQ depending on the quality of the service
• PSC depending on the result of the call back survey
IQT = [(PA + PQ) / (PA
+ PQ)max x 100 ] x 0,7 + PSC
x 0,3
Autorità per l'energia elettrica e il gas 86
Pos VENDITORE
PUNTEGGIO ACCESSO AL
SERVIZIO (PA)
PUNTEGGIO QUALITÀ DEL
SERVIZIO (PQ)
PUNTEGGIO INDAGINE
SODDISFAZIONE CLIENTI
(PSC)
PUNTEGGIO GLOBALE
(IQT)
1 EDISON ENERGIA S.P.A. 114 87 84,4 95,3
2 LINEA PIU S.P.A. 50 103 92,4 81
3 HERA COMM S.R.L. SOCIO UNICO HERA S.P.A. 44 107 90,1 79,6
4 A2A ENERGIA S.P.A. 31 100 98,8 75,3
5 TRENTA S.P.A. 35 71 98 66,3
6 SGR SERVIZI S.P.A. 44 58 100 65,5
7 GAS NATURAL VENDITA ITALIA S.P.A 45 59 95,4 64,8
8 TOSCANA ENERGIA CLIENTI S.p.a. (EX TOSCANA GAS CLIENTI) 48 59 89,7 64,2
9 E.ON Energia S.p.A. 44 50 89,6 59,6
10 AMG GAS S.R.L. 42 45 94,1 58,5
11 ENIA ENERGIA S.P.A 34 53 90,2 57,4
12 ITALCOGIM ENERGIE S.P.A. 39 50 85,1 56,5
13 ENEL SERVIZIO ELETTRICO S.P.A. 38 42 89 54,6
14 EROGASMET VENDITA - VIVIGAS S.P.A. 31 30 97,1 50,4
15 PROMETEO S.P.A. 42 13 100 49,2
16 ENEL ENERGIA S.P.A. 25 54 72 49,1
17 ESTENERGY S.P.A. 31 20 91,9 45,3
18 ASM ENERGIA E AMBIENTE S.R.L. 47 0 (*) 94,2 44,6
19 ASCOTRADE S.P.A. 42 0 (*) 95,4 43,2
20 ACEAELECTRABEL ELETTRICITA SPA 46 0 (*) 85,3 41,6
21 ACEGAS-APS SERVICE S.R.L. 41 0 (*) 89,4 41,1
22 ENI S.P.A. 53 0 (*) 75,3 41
23 IRIDE MERCATO S.P.A. 33 4 89,9 39,9
24 E.S.TR.A. ENERGIA,SERVIZI,TERRITORIO, AMBIENTE S.R.L. 34 0 (*) 91,4 39,3
25 AGSM ENERGIA Spa 30 0 (*) 91,3 37,8
Electricity and gas suppliers
more than
100.000 final
customers.
CALL CENTER PERFORMANCE RANKINGPUBLICATION (*) for the period Jul-Dec 2008
(*) On the web site of the Autorità + press release
Autorità per l'energia elettrica e il gas 87
AGENDA
• Overview on the electricity quality of service regulation
• Short overview on the electricity and gas smart metering regulation
Autorità per l'energia elettrica e il gas 88
METERING REGULATORY FRAMEWORK
Regime
Operator responsible for metering services
Accounting separation
Unbundling reform
Separation of the metering tariff
Functional unbundling in force
Regulated
DNO
2001
2007
2004 (from the distribution tariff)
2010
Electricity Gas
DNO (until 2008 Retailers could carry out meter reading)
2009 (from the distribution tariff and from the retail tariff component)
2012
Autorità per l'energia elettrica e il gas 89
SMART METERING REGULATORY FRAMEWORK
• Both electricity and gas sectors are covered by smart metering (and metering) regulations
• In both cases minimum functional requirements and deadlines (with penalties) for installation/commissioning have been introduced
• Electricity: Regulatory Orders 292/06 and 235/07 (in English: http://www.autorita.energia.it/docs/06/292-06allengnew.pdf)
• Gas: Regulatory Order ARG/gas 155/08: (in English http://www.autorita.energia.it/docs/08/155-08alleng.pdf)
Autorità per l'energia elettrica e il gas 90
SMART METERING - REGULATORY APPROACH
Two different approaches
• Electricity: judged unavoidable the implementation of smart metering at Country level (that’s for all DNOs) after the ENEL choice
• Gas: impact assessment (cost-benefit analysis, technical survey, …)
Drivers
• Need to pursue objectives
• Directive 2006/32/EC (transposed to the Italian legislation in May 2008 - decree n. 115/08)
Autorità per l'energia elettrica e il gas 91
WHY MINIMUM REQUIREMENTS• In order to guarantee:
the pursuance of the objectives
the same options to all customers (household/non household; free/in the protection scheme)
interoperability and standardization
• They should fulfil the following criteria:
system oriented
such as to avoid raising of barriers or limits to technical/technological innovation
such as to prevent the rejection of new solutions/architectures
be independent from telecommunications systems
Autorità per l'energia elettrica e il gas 93
WHAT DONE
• February/May 2006: made a formal request of information to Enel, Acea Rome and to major European manufacturers of smart meters (in practice smart metering systems were studied from the functional points of view)
• July 2006: published the consultation document n. 23/06
• December 2006: published the regulatory order 292/06, introduced:
– replacement obligations
– minimum functional requirements
• September 2007: introduced performance indicators for smart metering systems, for the time being only for monitoring purposes (regulatory order 235/07)
Autorità per l'energia elettrica e il gas 94
OBJECTIVES
• To help ensure competitiveness in the supply of electricity to residential and non-residential customers
• To establish the functional and technological conditions to make it possible to extend hourly metering to low-voltage withdrawal points also
• To improve the quality of the electricity metering, supply and distribution services for LV consumers and ensure the same functional and performance levels both for customers in the free market and those in the universal service
• (Not included in the R.O.): to look further some specific requirements, in particular consumption awareness (remote display) and demand response issues (home and building automation)
Autorità per l'energia elettrica e il gas 95
SMART METERS FOR LV CUSTOMERSMandatory timetable (1/2)
Installation CommissioningPenalty
(*)
25% 31-Dec-08 30-Jun-09
65% 31-Dec-09 30-Jun-10
90% 31-Dec-10 30-Jun-11
95% 31-Dec-11 30-Jun-12
100% 31-Dec-08 30-Jun-09
Household customers and non
household customers
with P<=55kw
Customers with P>55kw
(*) not recognized CAPEX for electromechanical meters not replaced
Each year of the period 2009-2012 DNOs are obliged to communicate to the Autorità the level of installation and commissioning of smart meters
Autorità per l'energia elettrica e il gas 96
• Starting from 1 January 2008, for each low-voltage withdrawal point through which the injection of active electricity into the network is activated, DNOs shall install one single smart meter, single-phase for single-phase applications and three-phase for three phase applications.
SMART METERS FOR LV CUSTOMERS
Mandatory timetable (2/2)
First step towards smart grids
Autorità per l'energia elettrica e il gas 97
Enel distribuzioneAcea RomaAem MilanoAem TorinoSet distribuzioneAsmea BresciaHera BolognaAgsm Verona
DNO% of LV customers equipped with commissioned
smart metersNo. of
LV customers
SMART METERS FOR LV CUSTOMERSCurrent status of the commissioning
plan
Snapshot at 30 June 2009 for major DNOs
30,063,1721,552,054
856,278554,992227,255220,893163,728159,328
95.4%57.8%28.2%31.0%27.6%92.4%32.6%31.3%
Autorità per l'energia elettrica e il gas 98
MAIN MINIMUM FUNCTIONAL REQUIREMENTS-AMM (1/2)
Specified for:
• Single phase mono-directional meters
• Single phase bi-directional meters
• Three-phase phase mono-directional meters
• Three-phase bi-directional meters
Autorità per l'energia elettrica e il gas 99
MAIN MINIMUM FUNCTIONAL REQUIREMENTS-AMM (2/2)
• TOU price scheme (weekly profile): up to four bands, up to five intervals per day (1 totalizer + 4 band registers)
• Interval metering (min. 1 hour, depth = 36 days)• Remote transactions [consumption reading (registers and
intervals), supply activation/deactivation, change of the subscribed power, change of the TOU tariff, power reduction]
• Security of data (inside meters, during the transmission to the control centre, status word with prompt transmission to the control centre in case of meter failure)
• Freezing of withdrawal data (billing, contractual changes, switching)
• Breaker on board of meters + demand control algorithm (alternative: registration of the peak power per TOU band)
• Meter display (current totalizer and activated TOU band registers, last freezing)
• Slow voltage variations (according to EN50160)• Upgrade of the program software
Autorità per l'energia elettrica e il gas 100
PERFOMANCE REQUIREMENTS • After the introduction of minimum functional
requirements, some performance indicators of AMM systems have been introduced (R.O. 235/07): Annual percentage of successful remote transactions
(activation/deactivation, change of the subscribed power, change of the price scheme, power reduction) within 24 hours and within 48 hours
Annul number of meters that at least once registered a failure reported to the control centre (through the status word)
Reading
frequencyThreshold
S
No. of meters with no. of successful readings below
threshold S
No. of meters with no. of successful readings
below 0Monthly 6
Bimonthly 3Three-monthly or
four-monthly2
Six monthly 1Annual 0
Autorità per l'energia elettrica e il gas 101
THE METERING TARIFF
• 2004: separated the metering tariff from the distribution tariff
• 2004-2007: the “extra-charge” for each household customer due to smart meters has been less than 2 Euros per year
• 2008-2013:– the X factor will be 5% for metering
activities (vs 1.9 % of distribution activities)– the metering tariff is/will be adjusted every
year
• An equalization mechanism is envisaged in order to recognize higher costs to smaller DNOs
Autorità per l'energia elettrica e il gas 102
INTERVAL METERS FOR HV AND MV CUSTOMERS
• HV customers and major MV customers have been equipped with interval meters (15min – 1 hour) since the second half of 80s
• In 2004 were introduced obligations for the installation of interval meters (1 hour) for all MV customers:
- P>500kW by June 2004- P=201-500kW by December 2004- P=101-200kW by December 2005- P<=100kW by December 2006
• Currently all HV and MV customers (free or under the protection scheme) are actually equipped with interval meters and treated on hourly base
Autorità per l'energia elettrica e il gas 104
GAS: WHAT DONE• July 2006: announced smart metering implementation in
the gas sector• May/October 2007: made a cost-benefit analysis, a
technical benchmark, a survey on the use of AMR/AMM systems in Europe
• July 2007: published the first consultation document (first thoughts)
• November 2007: established a WG (still alive) on “What minimum functional requirements for smart meters” (participants: the Autorità, DNOs, retailers, meters manufacturers, the Italian Gas Committee)
• February/April 2008: sent a request of information on installed meters to major DNOs
• June 2008: published the second consultation document (final thoughts)
• October 2008: Published the Regulatory Order ARG/gas 155/08
Autorità per l'energia elettrica e il gas 105
GAS: OBJECTIVES• To make it easier to eliminate any inefficiencies and
discriminatory features by improving the process of recording and accounting for the natural gas withdrawn by consumers and introducing technological innovations to metering units
• To create the functional and technological conditions for the introduction of mechanisms to develop a market system for natural gas and support the definition of the regulated market for natural gas and the new balancing service
• To improve the quality of natural gas metering, sales and distribution services, while ensuring the same functional and service levels irrespective of the operator responsible for the metering service and at the same time fostering greater awareness of consumption levels
Autorità per l'energia elettrica e il gas 106
GAS: TIMETABLE FOR THE COMMISSIONING OF SMART METERS
Commissioning deadline
Percentage
Penalty[€/meter non
commissioned]
> G40 31 December 2010 100%54
≥ G16 and ≤ G4031 December 2011
100% 21
> G6 and < G16
31 December 201130%
1231 December 2012
100%
≤ G6
31 December 2012 5%
4
31 December 2013 20%
31 December 2014 40%
31 December 2015 60%
31 December 2016 80%
Autorità per l'energia elettrica e il gas 107
GAS: TOWARDS THE ROLL-OUT (1/2)
Carried out in 2007:
• a survey on the use of gas AMR/AMM systems in Europe, found:
– projects running (in some cases combining electricity and gas)
– different technologies of involved meters in the system (traditional+data logger module/new generation meters)
Autorità per l'energia elettrica e il gas 108
Carried out in 2007:• a benchmark on gas smart meters, found:
– availability of new functionalities– availability of new measurement technologies
(mature, but with low level of industrialization) with correction of temperature and temperature+pressure
– some models already MID certified for both pressure and temperature correction or only for temperature correction
– availability of solutions with electrovalve on board– problems coming from the battery life: depends on
environmental conditions, on the frequency and the amount of data to be transmitted by the meter, on the use of the display, etc
GAS: TOWARDS THE ROLL-OUT (2/2)
Autorità per l'energia elettrica e il gas 109
GAS: SOME EX-ANTE DECISIONS• Quantitative cost-benefit analysis to be done DNO
side, that’s the actor that will make investments and meter reading activities
• Quantitative cost-benefit analysis to be differentiated according to the size of DNOs. Large (>500,000 consumers), Medium (50,000-500,000 consumers) and Small (<50,000 consumers)
• To be assessed both AMR and AMM (*) for household consumers (annual consumption < 5,000 m3) and only AMR for the others (annual consumption >5,000 m3)
• Pointed out a difficulty in carrying out a quantitative cost-benefit analysis consumer side in particular for households
(*) AMM = AMR + electrovalve on smart meter devices that cannot be opened remotely.
Autorità per l'energia elettrica e il gas 110
GAS: SOME EX-ANTE HYPOTHESES• No extra-charges for customers were assumed to
obtain the NPV shown in the following• Costs did not include the residual depreciation of
traditional meters due to be replaced by smart meters
• The periodical replacement of the power supply batteries was considered: once in the life-cycle of smart meters in the consumption band up to 5,000 m3/year and every two years for smart meters in the consumption band over 5,000 m3/year
• The installation, on average, of one data concentrator every twelve smart meters was assumed (more than 95% of smart meters will be managed through data concentrators)
• The costs needed to interface smart metering systems with billing systems were considered
Autorità per l'energia elettrica e il gas 111
GAS: FINDINGS OF THE COST-BENEFIT ANALYSIS (1/4)
Annual consumption bands
Size of DNO(no. of customers)
Large(> 500,000)
Medium(50,000-500,000)
Small(< 50,000)
Case 1: < 5,000 m3, AMM 1 – 1.18 1.27 – 1.46 3.14 – 3.35
Case 2: < 5,000 m3, AMR 1 1.26 3.33
Case 3: 5,000–200,000 m3, AMR 1 1.16 1.89
Case 4: > 200,000 m3, AMR 1 1.12 1.43
Case 5: < 5,000 m3, AMM (Case 1) ≥ 5,000 m3, AMR (Cases 3 and 4)
1 – 1.17 1.26 – 1.44 3.05 – 3.25
Cost of a single commissioned measurement point normalised to the cost of a large DNO
Autorità per l'energia elettrica e il gas 112
GAS: FINDINGS OF THE COST-BENEFIT ANALYSIS (2/4)
Annual consumption bands
Size of DNO(no. of customers)
Large(> 500,000)
Medium(50,000-500,000)
Small(< 50,000)
Case 1: < 5,000 m3, AMM 1 1.19 1.43
Case 2: < 5,000 m3, AMR 1 1.32 1.69
Case 3: 5,000–200,000 m3, AMR 1 1.09 1.19
Case 4: > 200,000 m3, AMR 1 1.06 1.13
Case 5: < 5,000 m3, AMM (Case 1) ≥ 5,000 m3, AMR (Cases 3 and 4)
1 1.17 1.37
Annual benefit for a single measurement point normalised to the cost of a large DNO
Autorità per l'energia elettrica e il gas 113
GAS: FINDINGS OF THE COST-BENEFIT ANALYSIS (3/4)
Annual consumption bandsSize of DNO
(no. of customers)
Large(> 500,000)
Medium(50,000-500,000)
Small(< 50,000)
Case 1: < 5,000 m3, AMM[1] -8 -11 -130
Case 2: < 5,000 m3, AMR -26 -23 -99
Case 3: 5,000–200,000 m3, AMR 613 685 633
Case 4: > 200,000 m3, AMR 1,151 1,227 1,182
Case 5: < 5,000 m3, AMM (Case 1) ≥ 5,000 m3, AMR (Cases 3 and 4)
7 6 -112
NPV at year 15 for different annual consumption bands [€/meter] AMM = AMR + electrovalve on smart meter devices that cannot be opened remotely.
Autorità per l'energia elettrica e il gas 114
• Quantified benefits (in Euros) were found for suppliers as well
• Those benefits were not used to assess the NPV shown in the previous slide
• From a qualitative point of view several benefits were assessed also for the “gas-system” as a whole
GAS: FINDINGS OF THE COST-BENEFIT ANALYSIS (4/4)
Autorità per l'energia elettrica e il gas 115
GAS: FOCUS POINTS• Compensation of Temperature and Pressure (the latter
not adopted for household customers)
• Electrovalve on board of meters for household customers (AMM for G4/G6)
• Parametrizeable interval metering (minimum interval: 1h for >= G10, 1 day for G4/G6)
• TOU withdrawal schemes
• Standardization and interoperability
• Battery life (and limitations implied by it)
• Communication between data concentrators and meters
• Installation of data concentrators (power supply, location)
• Potential displacement of meters
Autorità per l'energia elettrica e il gas 116
GAS: MIN. FUNCTIONAL REQUIREMENTS ADOPTED
Minimum functional requirement≥ G10(AMR)
< G10(AMM)
Metering units’ clock/calendar capable of managing seconds; synchronised with the same reading frequency; maximum monthly drift shall not exceed: Temperature adjustment. Measure of the gas withdrawn at standard temperature conditions (15°C).Pressure adjustment. Measure of the gas withdrawn at standard pressure conditions (1,01325 bar).Withdrawal totaliser register. One single incremental totaliser register.Time-of-use withdrawal totaliser registers. Three separate totaliser registers, three types of day, up to five intervals a day. Schedule updatable twice a year.Interval metering. 70-day capacity, minimum interval:Saves and backups of withdrawal totaliser register. Min. six-monthly, max monthly; whenever a new TOU schedule comes into operation. Withdrawal registers must be kept after the battery has been replaced or has run out.Withdrawal data security. Mechanisms to protect and monitor withdrawal registers.Diagnostics. Self-diagnosis checks, including one on the maximum monthly drift. Result recorded in a status word for transmission to the remote management centre.Display. At the customer’s request: date and time, current and last save withdrawal registers, the register active at the time of display, any alarm showing that the metering unit has recorded an anomaly.Electrovalve. Available on meters, cannot be opened remotely. During any power-supply failures it retains its state.Up-dating of the metering unit software programme.Information on real-time withdrawal. At customer’s request only (see the paragraph “Compliance with European Directive 2006/32/EC”).
3 min.
Yes
Yes
YesYes
1 hourYes
Yes
Yes
Yes
No
YesPulse
emitter output
5 min.
Yes
No
YesYes
1 dayYes
Yes
Yes
Yes
Yes
YesAdditional physical or
logical communication gate (regulatory framework still to be defined)