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Risk audit department Tour Initiale 1 terrasse Bellini-TSA 41000 92919 La défense CEDEX TEL: +33 (0)1 02 26 48 FAX: +33 (0)1 41 02 24 04
www.rte-france.com
RTE Réseau de transport d’électricité French société anonyme with a management board and supervisory board, and capital of €2,132,285,690 – listed on the Nanterre register of trades and companies
under number 444 619 258
Reliability report 2016
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authorisation granted by the Electricity Transmission Grid Operator (RTE)
Contents
Summary
1. Significant System Events
Page 4
2. Operational conditions encountered
Page 5
3. Equipment components reliability
Page 12
4. Tools, telecoms and IT
Page 14
5. Other operational levers
Page 16
6. Developments and changes to the network
Page 18
7. Contribution of human resources and
organisations to reliability
Page 19
8. Changes to the reference frameworks and
contractual rules
Page 20
9. Reliability beyond RTE in Europe
Page 22
10. Reliability audits
Page 24
Conclusion and outlook
Glossaries
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Summary
Every year, RTE produces a reliability report for the past year. This document lays
out the main factors that affected the electrical power system's operational
reliability in 2016 and the initiatives currently under way intended to ensure its
reliability in the future.
Withing a context of the energy transition, changes to the European interconnected
network mean that RTE has to adapt on an on-going basis. These changes include
the increase in the share of renewables injecting an intermittent power supply into
networks, resulting in a need for flexibility, and a diversification in the numbers of
stakeholders operating in the energy sector and changes in the ways in which they
behave.
These changes are dramatically changing the structure of the power system of
tomorrow and the way in which it will operate – particularly the way in which
voltage and frequency are controlled, as well as the distribution of flows, the power
system's stability, the level of reserves needed to ensure supply-demand balance,
network studies, assets' operating and control rules, the tools used and the
expertise of operators.
The results obtained in 2016 are evidence of a globally satisfactory level of
reliability for RTE's operations in somewhat demanding circumstances: more
complex supply-demand balance management, cross-border schedules at
interconnections indicating operation that is closer to its limits and – most
noteworthy – having to manage a cold spell just as several nuclear power plants
had been shut down.
In a drive to keep pace with the changes expected to occur in these circumstances,
RTE implemented numerous initiatives to ensure high levels of reliability:
- maintaining investment levels of €1.5 billion per year; - increasing cross-zonal capacity at borders with our neighbouring countries,
thus bolstering the security of our electricity supply;
- implementing new mechanisms (demand response, capacity mechanism, interruptibility, etc.);
- involvement in tests or projects (AMELIE, Ampacité, iTesla, APOGEE, etc.) designed to predict constraints on the future power system and develop new tools to tackle them.
And the Winter Packet, unveiled by the European Commission at the end of 2016,
which features numerous provisions designed to increase the reliability of the
power system and which has a bearing on the role played by transmission system
operators. RTE will ensure that it sheds light on the political issues which underlie
the technical provisions put forward and that appropriate measures are adopted
for reaching the objectives associated with the energy transition.
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1. Significant System Events Every year, RTE measures the reliability of the power system by adding up the
number of Significant System Events (SSE). These are classified according to a
scale of severity that ranges from 0 to F. These events correspond to incidents
that can result from a broad range of factors. RTE’s scale is more differentiated
and is compatible with the ICS (Incident Classification Scale) severity scale which
includes four levels defined by ENTSO-E.
Tracking the SSEs over several years flags up any weak signals which deserve to
be analysed in more detail. And the effectiveness of any initiative implemented to
increase operating reliability can be measured over time.
With 35 level A incidents and 2 level B incidents, 2016 was in line with the last
few years (see graph above). Worth noting in 2016 was the incident at the
Vigy substation, which was classified as a level C SSE. The last level C SSE
occurred in 2009.
The level C SSE deals with an incident
which occurred during a maintenance
operation at Vigy’s 400 kV substation.
The service provider tasked with doing
the work knocked a powered-down
busbar onto a powered-up busbar below
it with its handling equipment, resulting
in a busbar fault and the loss of eight
400 kV outgoing feeders, including a
nuclear power plant which islanded itself
in accordance with standard procedure
and an interconnection resulting in an
overload on the network, but without
any effect on consumption. A detailed analysis of this event highlighted the fact
that the operating and maintenance technicians had appropriately addressed these
consequences in real time, meaning that there are no significant recommendations
to be made in relation to the way in which the network was managed. (An analysis
of the human factor conducted resulted in recommendations for the company
tasked with doing the work).
45 41 37
57 55
2632
3830 29
35
4 2 1
85 3 3 2 1 2 21 1 1
4943
39
6660
2935
40
31 31
38
0
10
20
30
40
50
60
70
2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016
Increase in SSEs more severe than A
SSE A SSE B SSE C Total SSE > A
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2. Operational conditions encountered
Regarding the weather conditions, 2016 was another warm year: average
temperatures in France were 0.5°C higher than normal. However, it was not
particularly exceptional, and ranks as the 10th hottest year behind 2014 (+1.2°C),
2011 (+1.1°C) and 2015 (+1°C).
From a very general perspective, the following are noteworthy in terms of system
operation:
Storm Suzana which passed over part of France on 9 February (leading to
violent storms and winds of more than 115 km/h), but which did not result in
any power outages,
increased hydraulic operation compared with 2015 thanks to high springtime
rainfall and high levels of sunshine, good for photovoltaic electricity generation,
a summer heatwave which led RTE to monitor the forecast temperature
changes in its substations in order to prevent any consequences for the
measuring transformers following the incidents of 2015, in addition to the
earlier-than-expected campaign to replace them,
a new maximum of 8632 MW set for wind power generation on 20 November,
covering nearly 18% of France’s total power requirements, despite a fall in the
quantity of wind power generated owing to low wind speeds at the end of the
year,
a cold period coinciding with many nuclear power plant shutdowns during the
2016/2017 winter, mobilising RTE's resources so as to effectively predict
balance between supply and demand, widely involving neighbouring TSOs and
CORESO.
Continued growth in the share of renewable energies
The capacity of power generation facilities in mainland France increased by 1699
MW (+1.3%) compared with 2015 to reach 130 GW in 2016. This increase was
mainly driven by the growing share of renewable energies (+2188 MW),
which went a long way towards compensating for the reduction in fossil-fuel
thermal generation facilities (-488 MW), and the reduction in fuel oil facilities owing
to the two Aramon-based power plants closing (each one generating 685 MW).
Given its increasing share in the power mix, renewable energy production
– despite being decentralised – is playing an increasingly important role
in ensuring the stability and reliability of the power system (frequency,
voltage, margin, etc.). It requires increasingly flexible resources.
Total electricity generation in France was 531.3 TWh – a decrease of nearly 3%
compared with 2015. The fall in power generation in 2016 was mainly due to
reduced production at nuclear and coal-fired power plants.
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The development of renewable energies is a major component in the energy
transition. For RTE, the main challenge involves forming a sound
understanding of their variability and predicting it, so that supply-demand
balance can be properly managed, and the impact that they have on the network's
reliability can be forecast (flows, voltage, etc.). The demand response mechanisms
need to be adapted on a continuous basis so as to harness any potential for
flexibility among the various stakeholders and tackle the uncertainties associated
with renewables.
Record cross-border schedule capacities to improve system reliability,
despite particularly low cross-border schedules in 2016.
France's balance of trade for 2016 was
positive, with 39.1 TWh of sales. It can be
split into 71.7 TWh of exports and 32.6
TWh of imports. This is the lowest balance
since 2010. December even saw a very
slightly negative average balance of trade
– something which had not been seen
since February 2012. However, a new
positive record was set of 15.9 GW
between 5 PM and 6 PM on 31 January
2016.
Such high positive levels have been made
possible through the introduction of the France-Spain line which was brought into
service at the end of 2015, by flow-based market coupling across the Central
Western European zone and by competitive market prices.
The power system must be able to adapt to highly uncertain and extreme
weather conditions – particularly future cold spells
Power consumption peaked at 7 PM on Monday, 18 January 2016 at 88.6 GW. The
mild start to the year meant that this peak was relatively low.
Sensitivity to consumption currently shows a winter gradient estimated at
2400 MW per °C.
The last few relatively mild winters have had a tendency to hide the variability of
consumption levels – both in terms of annual energy consumption and peak
demand. However, even if the underlying trend is most likely heading towards an
average increase in temperatures, the power system must be able to cope with
any cold spells – the frequency and severity of which are difficult to predict. This
is why emergency training sessions for dealing with severe cold periods are held
on a regular basis so that operators can prepare themselves.
In the summer, the lowest power consumption was on Sunday 7 August 2016 –
30.6 GW.
Gross consumption stood at nearly 483 TWh in 2016 – that's 1.5% more than in
2015 owing to lower average temperatures.
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The significant variability in consumption shows that the power system
needs to be able to adapt to highly uncertain and extreme weather
conditions – particularly future cold snaps.
A management of the balance between power supply and demand under
surveillance
2016 saw 22 rising margin deficits and 4 that fell. The number of discrepancies
between forecast and actual power consumption was greater than in 2015. There
was also an increase in the number of alerts sent – mainly as a result of industrial
disputes among power generation companies.
Shortfalls in margins can – depending on how long they last and the time of day
at which they occur – impact reliability. The various initiatives that RTE has
implemented with the stakeholders involved should therefore be maintained in
order to strengthen contractual requirements and perform monitoring and
checking, making sure that power generation companies declare the technical
limitations affecting generation and actual availability via the Balance Mechanism.
Equivalent outage time not due to exceptional events was 2 minutes 54 seconds.
Although this result is still higher than the target of 2 minutes and 24 seconds that
was set by the French Energy Regulatory Commission as an incentive regulation,
it confirms the efficiency of the various initiatives put in place by RTE to improve
the quality of the power that it supplies to its clients. In particular, the accelerated
replacement of its measuring transformers and the operating provisions applied in
the event of temperature warnings limited the impact of this damage to 16 seconds
in 2016 (as opposed to 5 minutes and 44 seconds in 2015). This is almost
equivalent to pre-2011 levels – before damage to the measuring devices and
capacitor coupled voltage transformers during periods of very hot weather. It
should be noted that power outages resulting from various industrial disputes in
2016 added 32 seconds to total equivalent outage time.
Otherwise, equivalent outage time resulting from exceptional events rose to 3
minutes and 15 seconds as a result of two events that were classified as
exceptional, which together added 21 seconds. They involved infrastructure being
powered down during fires near Fos-sur-Mer and Vitrolles in France’s Bouches-du-
Rhône region at the request of the local authorities, as well as an act of vandalism
targeting the Salaise 63 kV substation in the Isère, resulting in a number of
customers experiencing outages.
The quality of the system's power-frequency control improved in 2016
across France, helping to manage frequency deviations in Europe.
The trend which got under way in 2013 which has seen an increase in the frequency
stability of the Interconnected European power system continued, with a fall in the
number of deviations greater than 100 MHz.
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Although falling frequency deviations (stable in 2016) are currently seen as the
most critical for the European system, in early 2016, RTE implemented
instrumentation and means for monitoring a high-frequency indicator. These
situations are now being tracked because of how potentially critical they are during
troughs in consumption, and more particularly at night when decreasing margins
are constrained. They can also be used to monitor the risk of massive photovoltaic
generation being tripped at 50.2 Hz during the day.
The IGCC (International Grid Control Cooperation) has been operational since early
2016 and is used to optimise secondary reserve procurement in France, helping to
improve the way in which frequency deviations is controlled in Europe.
A new project – "aFRR Assitance” – was launched in March 2017 designed to
enable the sharing of secondary reserve in the event of exceptional situations.
Through this system, a TSO could procure secondary reserve from its neighbour
in accordance with fixed and shared conditions.
Load shedding considered this winter during the cold spell.
Following the announcement regarding the reduced availability of a number of
nuclear power plants, seasonal studies conducted and published at the end of the
year by RTE within the framework of its public service remit highlighted the
operating risks to the system in the event of a cold spell. Measures were therefore
taken in order to prepare RTE for a possible supply-demand balance crisis and
inform stakeholders operating on the power system and the general public of the
exceptional and progressive means that might be put in place in order to ensure
system security.
A warning system was developed in close cooperation with the public authorities
and the Distribution System Operators as part of preparations to manage a
possible crisis. Otherwise, significant work was done on the market operating rules
(the capacity mechanism was introduced, a number of provisions to do with
demand response were reviewed) in order to secure the involvement of all
stakeholders in the power system and to remind each one of the responsibilities
incumbent upon them. In concrete terms, this work resulted in the stakeholders
mobilising at the start of 2017. A successful balance between consumption and
generation was attributed to all possible power generation means being used in
France (particularly ones involving renewable energies), to imports, to demand
response mechanisms and to people behaving more responsibly in relation to their
energy use. Cooperation with CORESO once again proved effective in preparing
the system for operation in real time. Furthermore, within the framework of this
unusual situation, RTE’s neighbouring TSOs worked together exceptionally in order
to maximise cross-border schedules (resulting in a departure from a number of
operating rules in order to maintain the power supply). For example, planned
works were postponed by a number of TSOs and RTE implemented exceptional
and temporary measures to increase cross-border schedule capacities by departing
from standard operating procedures, particularly those relative to service quality.
An inter-zone frequency oscillation phenomenon observed
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On December 1st 2017, the unexpected opening of a 400 kV breaker in south-
western France triggered a
frequency oscillation
phenomenon right across
European network. When
this happened, the rotor
shafts of generating units
in Turkey and the Iberian
Peninsula started
oscillating out of phase
relative to generating units
in Central Europe.
The phenomenon lasted for several minutes until the Spanish system operator REE
started reducing cross-border schedules between Spain and France (for its own
reasons). This led to the oscillatory phenomenon being reabsorbed.
Detailed studies were initiated by specialists in this field at RTE, as well as at REE
and ENTSOE. This is a major system security issue and it is important to determine
whether this phenomenon was the manifestation of a set of structural
circumstances, or simply the unfortunate convergence of several factors. We need
to determine the importance of the way in which the "Baixas-Santa Llogaia” direct
current line was operated.
2.2 Voltage management
The last few winters have not led to any particular difficulties in terms of
low voltage management. The two defence automata (in the west and in the
north) which are part of the voltage collapse defence plan were only armed once
in 2016. But the thresholds below which the west and north defence automata are
triggered were not reached. No safeguard order for low voltages (-5%, One,
adjuster lock) were issued during the year.
In 2016, the number of upper normal voltage range threshold overruns – together
with the total duration of these overruns – was more than halved. But there are
still too many of them. Around thirty 400 kV substations are still affected by
voltage ranges being exceeded. For the 225 kV network, normal voltage range
threshold are exceeded at 574 substations, with significant disparity from region
to region. As far as reliability is concerned, high voltages are less dangerous than
low voltages (risk of network collapse). But they can affect the service life of
equipment, as well as contractual voltage ranges for customers.
Despite the same number of substations experiencing overruns as in
2015, a reduction in the number of overruns and their total duration is
evidence of these phenomena being more effectively managed by RTE.
Tests in collaboration with Enedis were conducted in order to assess the utility of
using the reactive power capacity of generating facilities connected up via MV
power lines, and more specifically wind power facilities in order to address voltage
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overruns on the transmission grid: one was conducted in France’s Picardy region
in August 2016, and two others were initiated at the end of 2016 (Vendée and
Hauts de France), with a view to their being carried out in summer 2017.
To control voltages on its
network nodes, RTE has
installed considerable
compensation means over the
past 12 years. In 2016, 700
Mvar of capacitors were
connected up (low voltages in
the action zones of the Paris,
Toulouse, Marseille and Nancy
regional control centres) and
nearly 500 Mvar of inductors
(high voltages in the Marseille, Nantes, Nancy and Lille regions).
New investments in inductor-type compensation means are scheduled for the
years ahead, but installing capacitors beyond 2017 can no longer be justified.
2-3 Interconnections and international flows
Overall, flows across the French network were well managed in 2016. This can be
attributed to a number of cyclical factors, as well as structural and organisational
factors, including improvements in the efficiency with which the regional
grids are managed through CORESO (coordination of electrical system
operators). This has enabled effective coordinated initiatives to be implemented
among TSOs – as was the case during this winter's cold snap.
There were six 20-minute overload start-ups on the 400 kV network and
interconnection links in 2016. Although such occurrences are relatively rare and
so should not be used as the basis for any statistical interpretations, it would still
seem that some of them are evidence of an underlying trend that involves
maximising cross-zonal capacity. This situation also illustrates the utility of
performing calculations as closely as possible to capacity allocation limits with
assumptions that change more and more between D-1 and real time, as well as
on an intradaily basis.
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The France-Spain HVDC interconnection that came into operation in October 2015
made commercial cross-border schedules between France and Spain of up to 3500
MW (export) and 2983 MW (import) possible in November 2016. Average available
capacity in 2016 was 2425 MW for exports and 1950 MW for imports – which is
more than double what was available the year before this new line was brought
into service.
France has never exported or imported energy across the Spanish border
so much as it did in 2016. France exports power to Spain (72% of the time)
much more frequently than it imports it.
This balance of trade reached a new export record for the Iberian Peninsula: 7.8
TWh, as opposed to 7.3 TWh in 2015.
This winter, at peak evening times of the week from 16 to 20 January 2017 during
the cold snap, Spain exported more power to France than any other country (an
average of 1352 MW; behind Belgium (1015 MW) and Germany (772 MW)).
Flow-based market coupling across the Central Western European zone
can be used to operate interconnections as close to their limits as
possible, while at the same time maintaining the required operational
security margins. Convergence rates between French prices and those of
neighbouring countries are on the increase across all market coupled borders.
In 2016, price convergence in the Central Western European zone rose to
35%, as opposed to 19% in 2015. Average spreads between French, Italian and
Spanish prices are decreasing, partly thanks to the increase in cross-border
schedule capacities at these borders. Unusual convergent situations are regularly
recorded – as was the case between 1 PM and 2 PM on 19 January 2016: prices
were identical from Portugal to Finland. In terms of reliability, a price
convergence between two countries also indicates that there is no
network congestion forecast at these borders.
After consultation with market parties and in line with the principles set by
European network codes, RTE has implemented mechanisms designed to open up
the French electricity market and facilitate its integration in Europe. As a result,
several exchanges will be competing in France by mid-2017 at the earliest.
This will bolster the French market's liquidity.
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2.4 Short-circuits affecting transmission structures
The number of short-circuits (7912) affecting transmission structures fell
for the second year in a
row (8352 in 2015 and
9818 in 2014). This fall
can be explained by a
lower number of lightning
strikes. Across France as
a whole, the main causes
of short-circuits are
naturally atmospheric in
nature: 29.7% were due
to storms, and 5% were
due to wind and floods.
Sticking snow was
responsible for 0.9% of
short-circuits this year,
and damage to equipment accounted for 2.2% of all recorded causes. There were
encouraging results in 2016 (0.6% of short-circuits) for controlling vegetation,
evidence of just how useful long-term initiatives and the resources allocated have
been.
The share of permanent faults accounted for 3.7% of the overall total – slightly
lower than in 2015. And the situation improved with only 4 double 400 kV faults,
of which 1 involved a definitive tripping.
In 2016, work began on testing AMELIE (a weather warning system for overhead
power lines), alerting RTE in the event of any weather events likely to result in
short-circuits on the network. These warnings tell RTE when to deploy technical
and human resources for tackling these incidents and help ensure that nominal
operation is restored as quickly as possible on the network.
In 2016, work began on deploying the LAD service (automatic fault location),
designed to power undamaged infrastructure back up as quickly as possible during
storms. Deployment is scheduled to be completed by 2020.
3. Equipment components reliability
3.1 Generating units
Twice a year, electricity generators and RTE hold discussions about the multi-year
program to bring down the limitations of the reactive capacity of nuclear power
plants, in terms of both supply and absorption. These limitations can be
disadvantageous for managing low voltages (risk of collapse) or high voltages
(risks for equipment). There were more imbalances in 2016 than in 2015 and
Répartition des causes de courts-circuits sur le réseau de RTE en 2016
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resorption times could prove constraining depending on the adjustments needed
between now and winter 2018/2019 in northern France.
Individualised per-unit Secondary Voltage Control for finer voltage
management:
This option to individualise the level was introduced in 2016 in the secondary
voltage control and can be used to more finely manage voltage without affecting
the interface with the generating unit.
The first renewable energy facilities subscribed to secondary voltage control
appeared in 2015 and 2016 following the introduction of a specific command. This
relates to the Justice wind turbine facility (74 MW on the 225 kV Nantes network)
and the Constantin photovoltaic facility (230 MW on the 225 kV Toulouse network),
certified in 2016.
In 2016, the combined cycle power plant in Bouchain and the biomass facility in
Guerache were the first thermal power plants to be certified for performing this
type of control.
This change will be rolled out to hydraulic power units in 2017.
92% of trials to island nuclear power plants in compliance with
objectives:
The successful islanding of nuclear power plants in the event of a widespread
incident is important for nuclear safety and is vital for recreating the network and
restoring power supplies to customers. In 2016, 14 islanding trials (from full
power) were carried out on the nuclear power plants (including 2 accidental ones):
13 island operations were successful – the equivalent of a 92.3% success rate (as
opposed to 77% in 2015), and an 85% success rate over a four-year rolling period
to be compared with a 60% multi-year ceiling target.
3.2 Network equipment
On the 400 kV network, 383 short-circuits were eliminated in 2016 (385 in 2015),
340 of which were single-phase faults. The response rate in compliance with the
soliciting of protection devices and automata in the event of electrical faults on
400 kV networks is in compliance with regulations: a 96% compliance rate on
400 kV networks. Furthermore, the good results on the "225 kV HDP (high-density
production area and close) network" is evidence of the specific protection plan for
these networks being effectively deployed following a reliability audit conducted in
2011.
The 400 kV differential busbar protection devices play a major role in the fast and
selective elimination of busbar faults, which although very rare present a high risk
in terms of reliability and were behind 9 SSEs (10 in 2015). Their 99.5% availability
rate has remained stable.
Protection devices involving ring opening upon loss of synchronism are part of the
Defence Plan and play an essential role in isolating those network zones which
have lost synchronism from other zones which are still healthy in the event of a
major incident. This prevents the incident from spreading. Although they are only
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very rarely used, they need to be able to respond reliably if required. In 2016,
there were no operating anomalies and the ring opening upon loss of synchronism
plan was reliability-audited, indicating that the whole system is properly managed
overall.
The Ampacité project sets out to test a more flexible type of operation,
determining cable transmission capacities in real time depending on external
conditions measured (temperature, perpendicular wind, sunshine levels, etc.) so
as to generate additional margin and optimise available remedial actions. These
measures, which ensure that the way in which infrastructure is used is optimised
for its particular physical characteristics, help facilitate the incorporation of
electricity generated by wind turbines and improve the quality of the power supply
to customers, reducing the number of operating constraints and the associated
power outage risk.
Within the framework of this project, the 400 kV Tavel-Réaltor line was fitted with
sensors at the start of 2017, and three other 63 kV and 90 kV lines are set to be
fitted with them later on this year in Lille, Nantes and Nancy. These projects will
serve to validate the valuation assumptions and test their implementation. The
Ampacité project is set to be made available in full operational conditions
in 2018.
4. Tools, telecoms and IT
4.1 Tool
In 2016, two incidents involving accidental unavailability with shut-down of
transmission at secondary load-frequency control level for 3 minutes and 1 minute
respectively affected the National Control System (SNC). The main focus in 2017
will be on improving the National Control System so it can address the demands
of the "aFRR Assistance" project, the purpose of which is to implement an inter-
TSO support function for secondary reserves.
In 2016, 5 “0” level SSEs were recorded (as opposed to 11 “0” level SSEs and 3
“A” level SSEs in 2015) on the Regional Control Systems (SRC). All the accidental
events taken together in 2016 resulted in a total loss of observability of 1 hour
and 2 minutes – significantly lower than in previous years (16 hours and 15
minutes in 2015).
During the course of 2016, the regional inter-dispatching support centre (SIDRE)
– which has been operational since June 2015 across the three inter-regional units
– was only activated once in order to tackle a real need. The year was used to test
two usage modes (short mode with activity resumption over a few hours and long
mode with activity resumption over several days) with 42 short activations and
one long activation.
In order to deal with the ageing of the control systems currently in use and to
provide operators with a unique control system built around the market's SCADA
supervision system, RTE has launched the STANWAY project. This new tool is
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scheduled to be brought into service for the first time in 2019/2020 for the National
System Operating Centre, then for the 7 Regional Operating Centres.
The average monthly number of remote commands issued per Operations Centre
is around 8600, with amplitude varying from centre to centre. The annual average
unavailability rates for the remote measurement and remote signalling systems at
the 7 regional operating centres are 1.33% (1.42% in 2015) and 0.17% (1.14%
in 2015), respectively.
The Safeguard Alarm System (SAS) is a vital tool for managing high-risk (alert
orders) or downgraded (safeguard orders) situations, during which availability and
reliability need to be excellent.
In 2016, 38 "0" level SSEs and 1 “A” level SSE were logged. The high number of
SSEs can mainly be explained by messages not being acknowledged by generators
and distributors during periodic tests conducted by RTE. A reminder was issued to
ensure that people respond in compliance with expectations in high-risk or
downgraded situations requiring the use of the Safeguard Alarm System.
The Convergence test platform is the reference tool used to conduct
electrotechnical tests to prepare for operation in real time. It is used by RTE and
CORESO. The theoretical availability rate of the Convergence servers was excellent
– 100% in terms of real-time activities on D+2.
The system for including the production of intermittent renewable energies into
the power system (IPES) is used for short-term tests and during operation in real
time; it supplies estimates about the actual quantities of electricity generated by
wind farms and photovoltaic cells, as well as forecasts for these renewable sources
locally, regionally and nationally. It can do this for adjustable periods ranging from
D-4 to D+2, at frequencies selected by the user.
At the end of 2016, the total observable power generated by renewables either
directly by the producer’s remote operation, or via means put in place following
agreements entered into with partners (producer associations, Distribution System
Operators, etc.) was 17.7 GW for 18.4 GW of installed capacity. In order to tackle
the growing volume of data about renewable energies, in 2016 RTE continued
thinking about ways of ensuring the long life of the system to include the reduction
of intermittent renewable energies in the power system, and results are expected
by the end of 2017.
The Voltage Map application was declared
operational following a prototyping phase.
This enables users to visually monitor the
voltage plan at national or local level and
issues warnings in the event of voltage
overruns.
Within the same framework, the LUCA
project began in 2016. The purpose is to
conduct automatic system security
analyses on projected network situations.
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4.2 Telecommunications and IT system security
The operational reliability of the power system is closely linked to the sound
operation of the security telecommunications networks on the one hand, and the
IT system on the other with its capability to face threats such as cyber-attacks.
The "ROSE" Optical Security Network, an infrastructure owned and operated by
RTE, is distributed over approximately 20,000 km of optical cable and provides
telecommunication services which contribute to system security: "high-level"
remote operation (observability, manoeuvrability, control), exchange of
information with protection against electrical faults, safety telephone.
2016 saw two level “B” SSEs affecting the optical infrastructure used by ROSE in
the Toulouse zone and a level "0” SSE in the Nancy zone following one or several
optical fibres being cut.
One level “A” SSE affected operation of the Safety Telephone System in 2016
(malfunctioning of an automatic switch reset manually), together with nine level
“0” SSEs. Actions scheduled to be implemented in 2017 mainly involve testing
STS2 architecture (implementing a Disaster Recovery Plan exercise, redundancy
operation).
The security of RTE's IT system is key to ensuring the reliability of the power
system's operation. This applies in particular to the command control system and
remote management activities, as well as to the way in which information is shared
with customers, market parties and partners.
RTE’s Operational Security Centre (COrS’R) thwarted several IT warning situations
in 2016 (outsmarting around 4300 attacks every month, preventing 1000 spam
emails from getting through and eradicating 200 viruses across RTE's IT system).
RTE was involved in the 2016 PIRANET cyber-attack government plan organised
by France's public authorities. It served as an opportunity to apply RTE's internal
IT security expertise and to form links with government departments.
5. Other operational levers
Greater collaboration between the transmission grid and the distribution
grid
With a network that is both more limited and more difficult to manage as a result
of decentralised production and smart grid projects, exchanging information
between the distribution grid and the transmission grid and having a sound
reciprocal understanding of the difficulties encountered are now vital for controlling
the future operation of both networks and managing relations with interfaces.
In 2016, RTE and several Distribution System Operators undertook projects in a
number of areas. They involved managing automata, sharing operations data and
managing voltages at the transmission grid/distribution grid interface.
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Three shared roadmaps have been drawn up for these projects, clearly defining
their targets and timescales. They will be extended to include other French
Distribution System Operators.
Consumption moderation and demand response schemes
Demand response is a source of flexibility that involves consumers waiving or
postponing some or all of their power consumption in response to a signal. Demand
response can be used by market parties to optimise their own portfolios or to sell
energy directly to other stakeholders or to RTE.
Demand response is now a source of power and flexibility for managing
supply-demand balance and frequency in the same way as it is for
managing production. It is an additional lever for ensuring operational
security.
In 2016, 1875 MW of demand-response capacity was certified as part of the
capacity mechanism for 2017.
Furthermore since November 1st 2014, RTE has been managing the Tempo signal
project and has been featuring it on éCO2mix so that all suppliers can offer their
demand-response electricity supply packages.
For the third year, companies have been able to use the new NEBEF mechanism
(Notification of the Exchange of Curtailment Blocks) to adjust demand response
valorisation rules directly on the market. By the end of 2016, 24 companies (6
more than in 2015) had entered into contracts with RTE to be part of this
mechanism. Although the demand response volume on the NEBEF demand-
response mechanism (that rewards demand-reduction efforts) is still relatively
modest regarding the potential that some stakeholders give to it, it is enjoying
healthy growth and reached 11 GWh in 2016.
In December 2016, RTE formalised the use of its educational éCO2mix
application as a new means for issuing alerts within the framework of its crisis
communication system. So when exceptional resources are mobilised during the
power system's high voltage periods, the éCO2mix application sends out national
and/or regional warning messages, suggesting that consumers reduce their energy
consumption by adopting more environmentally-friendly behaviour.
The environment-responsible EcoWatt initiative, deployed in Brittany and in
the Provence-Alpes-Côte d’Azur region as a means of addressing weaknesses in
the electricity supply, has also been designed to encourage people to moderate
their power consumption, particularly in the winter and at peak times.
EcoWatt has a total of 58,200 EcoWatt players in Brittany and 32,000 in France's
Provence-Alpes-Côte d’Azur region, where the warning system now kicks in during
peak power demand at regional level.
The capacity mechanism is designed to secure power supply in the long term in
France, particularly during peak demand periods. By remunerating the availability
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of generation and demand response means, the capacity mechanism encourages
stakeholders operating on the power system to maintain and develop – at the
lowest possible cost – the demand response and generation means needed to
secure power supply in the long term. By December 31st 2016, total capacity
of 92,148 MW had been certified by RTE, nearly 2 GW more than the
criteria for securing power supply.
6. Developments and changes to the network
In 2016, RTE invested a total of €1519 billion across the perimeter
regulated by the French Energy Regulatory Commission. Among the main
investments were the bringing into service of the 400 kV line between Charleville
and Reims, the continuation of construction work (on the French side) on the direct
current interconnection between France and Italy that passes through the security
duct of the Fréjus tunnel, reconstruction of the Haute Durance 225 kV network and
the 2 Loires project to rebuild the 225 kV line interconnecting the Auvergne region,
the Rhône Valley and the Massif Central, as well as the Brittany safety net. Around
60% of investments was for existing infrastructure.
Future changes and adaptations to the network are underpinned by a
forward-looking approach which involves the following projects:
The 2016 provisional long term forecast plan on power supply-demand
balance in France is the first link in the reliability chain – it is the starting point for
developing a set of potential supply-demand balance scenarios which will then be
broken down into "network hypotheses" for use with all national and regional
network development studies up until 2030. For the first time, it points to an 8
TWh reduction in France’s annual electric power consumption by 2021,
mainly as a result of energy efficiency measures. The security of the power supply
level from 2016 until 2021 will be influenced by the conditions under which the
French capacity mechanism is implemented, which itself will be influenced by the
debate on the price per tonne of emitted CO2.
RTE published a new edition of its ten-year grid development plan on
completion of the public consultation which ended in January 2017. This ten-year
plan is a break from previous editions and lists all the adaptations which will need
to be made over the next three years and the main infrastructure that should be
considered over the next ten years. The actions which have been chosen are
detailed in the "Impulsion & Vision" project. In this particular corporate project,
the "digital revolution" and "technological breakthrough" challenges will result in
the creation of five "New Generation" substations between now and 2020 and the
deployment of digital control systems at all RTE substations by 2030, as well as in
50% of the network being equipped with monitoring solutions by 2030 in order to
adjust maximum network capacities based on weather conditions or in response
to multiple equipment measurements.
In line with and as a continuation of the Ten-Year Network Development Plan and
the provisional forecast plan, more than 400 projects are discussed in this plan –
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many of which are in response to the challenges associated with the energy
transition. These projects are designed to facilitate the incorporation of the new
production mix both in France and abroad, and support localised changes to
consumption, as well as ensuring solidarity in terms of access to electricity among
regions.
In addition to inter-regional cross-border schedules, RTE is also developing
interconnections between France and its European partners. Taking all borders
together, an increase of up to 10 GW in interconnection capacity is being
investigated or has been proposed with a view to being brought into service within
the next decade.
7. Contribution of human resources and organisations to reliability
An approach based on Human Security Organisational Factors at RTE
At the end of 2015, RTE launched an ambitious program designed to develop the
security culture across the company with the help of the ICSI (France's industrial
safety culture institute). An assessment was conducted targeting 1500 employees
from eight pilot entities focusing in particular on jobs in operations, maintenance
and development.
This assessment highlighted a high degree of shared involvement among all
stakeholders, but for some of them, it also pointed to the opportunity to adopt a
more systematic approach to security-related behaviour.
The improvement initiative is based on the fact that implementing a safety culture
development program across the company will ultimately improve the operational
security of the way in which the system works. It will also generate benefits in
terms of production quality and improving health and safety in the workplace.
Improved Performance through Professionalism
An inter-profession seminar on Human Factors was held in March 2016, the aim
being to share information about progress made with the Human Factor initiative
at RTE. This seminar served as an opportunity to present the first results of the
assessment conducted by the industrial safety culture institute, as well as details
of the benefits provided by the Improved Performance through Professionalism
initiative. This initiative involves capitalising on and sharing Human Factor type
differences, regardless of whether or not they have consequences on industrial
safety in the broadest sense, the aim being to collectively improve performance.
In 2016, 634 “Improved Performance through Professionalism” events were
declared in the field of operations, and served as opportunities to analyse weak
signals in this field.
Training and skills maintenance initiatives which are being continuously
adapted
In addition to the annual training program available for maintaining operatives'
expertise – including days during which exceptional circumstances are simulated
– many projects and changes in doctrine have required special training in
operations-related areas.
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The centralised training program is regularly modified in order to ensure that they
are in line with changes on the network, kept up-to-date with the fast and
numerous changes to the methods and tools used for conducting assessments and
managing the network and for preparing and carrying out work on the transmission
grid's infrastructure. In 2016, two crisis management courses for technical on-duty
staff and on-call management staff were created in order to expand the range of
training courses available for this activity. Also in 2016, the first inter-centre
distance training test was conducted in circumstances in which distance learning
methods play an increasingly important role in training.
Local training program play an additional role in helping operatives to acquire and
maintain their skills. The important role that coordinators, intake mentors and
managers play in enhancing people's professionalism out in the field also needs to
be emphasised.
There were very few visits from outside parties in 2016 because of the
antiterrorism measures that have been put in place in the wake of the attacks in
France. However, there were a number of meetings with generators and
distributors' management centres in all regions of France, and a number of "Let's
guarantee reliability together" courses were held for Generators and Distributors
in partnership with the Performance Testing unit.
Regarding preparing stakeholders, 2016 also saw a significant number of
national and regional crisis management exercises.
In addition to the numerous exercises conducted by all Operations Centres, two
major national exercises were carried out:
the "Measuring Transformer" exercise, conducted in May 2016 to prepare
operatives for the risks involved in operating measuring transformers in
extremely warm periods before summer 2016;
the "Managing Electricity Supply/Demand Balance" crisis exercise in early
December 2016, in partnership with government departments (zonal
operational centre, regional department for environment and housing, etc.) and
ENEDIS.
These exercises were opportunities to consolidate all the operational documents
managed by ORTEC (RTE's crisis structure) for these situations and to maintain
numerous employees' skills at local level.
8. Changes to the reference frameworks and contractual rules
Focus on the new European "Clean Energy for All Europeans" raft of
legislative proposals.
On 30 November 2016, the European Commission unveiled a package of
measures, collectively known as the "Clean Energy for All Europeans" legislative
proposals. Its aim is to make changes to the European framework, implement the
aims of the energy-climate packet and continue putting together the Energy Union.
This package of legislative proposals focuses in particular on the market design,
the aim being to adapt it for use with renewable energies and the incorporation of
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new flexible means into the system (demand reduction, storage, etc.). It also
contains an important section on regional cooperation between TSOs and
structural measures regarding the tools which can be used to secure the energy
supply (definition of criteria, capacity mechanism, etc.). The proposals also
concern adapting the way in which all energy issues are governed at regional and
European level.
These proposals are therefore important issues for France, for RTE and for all
stakeholders involved in the power system, including future responsibilities for
ensuring the power system's reliability. Discussions about these documents are
already under way with the European Council and European Parliament; the
Commission would like them to be definitively adopted by 2019. In particular, RTE
will clarify the underlying political issues associated with these technical provisions
and will proactively ensure that this new energy packet is appropriate for the task
of creating a fully-fledged, sustainable Energy Union. It will ensure that it meets
the power system's needs in compliance with the principle of subsidiarity, creating
an environment in which innovation can develop at a time when the sector is
having to address wide-ranging changes.
The main changes to the Technical Reference Document in 2016 pertain to:
the introduction of the Operating and Management Agreement template, and of
the Connection Agreement template for New Exceptional Interconnections used
within the framework of the Eleclink project (designed to connect up a private
interconnection via the Channel Tunnel).
Work has been undertaken or will continue into 2017 together with clients in order
to make changes to other articles. This work relates to the sharing of information
and the remote management system for power generation facilities, consumers
and distributors, together with the voltage ancillary service rules.
Towards management of the risk of a massive triggering of renewable
generation
In 2016, in order to address the risk of a massive tripping of photovoltaic
generation when the 50.2 Hz in 200 ms threshold is exceeded, RTE and ADEEF
adopted a joint position designed to maintain reliability. It mainly involves the
thresholds being gradually raised for new connections (50.4 Hz, then 50.6 Hz) and
alternative production means being qualified for new connections.
In 2016, situations whereby generation is tripped based on frequency criteria of
less than 49.5 Hz were also addressed, with alternative protection being qualified
for new connections, as well as by devising a technical solution the deployment of
which is in the process of being finalised with the regulatory authorities.
System Services
The work that RTE carried out in 2016 on Voltage System Services has resulted
in changes to terms of payment designed to make the system both more
transparent and easier to understand. These provisions came into force on April
1st, 2017.
As far as frequency ancillary services are concerned, since January 16th, 2017
RTE has been meeting its frequency containment reserve requirements via a
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weekly invitation to tender issued jointly with TSOs in Belgium, Germany,
Switzerland, Austria and the Netherlands.
In 2016, industrial site contracts for frequency containment reserve were
formalised and primary industrial sites for secondary reserve were certified. At the
end of 2016, certified power for the frequency control of consumption sites stood
at 92 MW (of which 25 MW of secondary reserve). This potentially equates to 16%
of France's required frequency containment reserve. It should be noted that
this reserve includes the first RTE certified battery for voltage control (1
MW, on the distribution grid).
Balancing mechanism
In 2016, RTE entered into FRR and RR capacity contracts with nine suppliers in
order to ensure a 1000 MW volume of rapid reserves that can be activated in less
than 15 minutes, and 500 MW of complementary reserves that can be activated in
less than 30 minutes. The contractually-agreed volumes of FRR now stand at 1278
MW, 47% of which is supplied by demand response (against 20% for the previous
period) and 53% by generation. Regarding RR, demand response covers 4% of
the subscribed volume, and the remaining 96% is covered by generation.
Changes in contracts over the last few years highlight the growing contribution
of industrial demand response on the one hand, and the increased vigilance
with which RTE manages supply-demand balance in real-time on the other. This
vigilance is manifested by strict checks on the performance of insuring parties
and the processes involved in renewing approvals.
9. Reliability beyond RTE in Europe
In 2016, the Requirements for Generators code setting out a set of connection
conditions for all generators was discussed in France with a view to applying some
of the thresholds, and the DCC and HVDC codes were published in the European
Union’s Official Journal.
In 2017, the European System Operations Guidelines and Emergency and
Restoration network codes will be prepared and will then come into force.
The fourth edition of the TYNDP (Ten-Year Network Development Plan) was
published in 2016.
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It sets out the ways in which Europe's transmission network will develop between
now and 2013 in order to complete the energy transition and create the European
single energy market. The important
role that direct-current technology
plays in this plan should be noted.
The following issues in particular will
have a major impact on the way in
which the system is managed over
the next few years:
Europe's future energy mix which
will ensure that between 45% and
60% of power consumption needs
are met by renewable energies,
with specific initiatives designed
to reduce the limitations of
electricity generated by wind power,
interconnection capacity which is set to double in Europe by 2030, particularly
so as to enable a more effective incorporation of peninsulas into the European
electricity market (Portugal/Spain, Italy, the Baltic states, Ireland, the UK).
Cooperation between TSOs
On October 28th, 2016, RED Electrica, the
Spanish transmission system operator, became
a new member of CORESO.
CORESO is one of 6 RSCs (Regional Security
Cooperations) in Europe located in Brussels
which supplies cooperation services to 7 TSOs.
This ensures the power system's security at
European level.
CORESO is taking on increasing numbers of
coordination tasks across increasingly large
regions.
Irish TSOs (Eirgrid and SONI) are in the process
of becoming members. This should be finalised
in 2017.
As far as R&D and major European projects connected with reliability are
concerned, the following key developments should be noted for 2016:
APOGEE project: In 2016, this decision-support system aimed at developing a
hypervision environment underwent an initial off-line test phase so that operators
could test the "periodic manoeuvres" module. Online testing started in May 2017
at the control centre of RTE’s operations centre in Nancy.
iTesla project: iTesla foreshadows the next generation of network security
analysis platforms which use a probabilistic approach to analysing the risks
incurred during operation, factoring in possibilities for curative workarounds and
dynamic phenomena.
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Migrate project: This project involves preparing for the power system's operation
by incorporating significant quantities of power electronics equipment (HVDC links
and connecting up renewable energies).
Substation of the future: The purpose of this project is to use demonstrators to
redesign the functional architecture of substations in response to the new
requirements of the power system. It incorporates environmental targets into its
design and technological solutions that will likely be implemented in the decades
to come. In 2017, the functional components of BLOCAUX’s "Smart Substation”
were brought into service and will be used in observation mode in 2017. "Action"
mode is being considered for 2018.
Direct current networks: In 2016, the second year of work using the project's
demonstrator operated by RTE helped create all of the study scenarios using the
numerical models supplied by the constructors. At the same time, the European
"PROMOTION" project (PROgress on Meshed HVDC Offshore TransmissIOn
Networks) was launched in early 2016 for studying the interoperability of
protection schemes in use on direct current networks. The results are expected in
2020.
GARPUR project: In 2016, work focused on developing a new probabilistic
method for isolation procedures, as well as for assessing a maintenance policy.
10. Reliability audits
The issues on which audits are focussed, are designed to ensure that all the major
aspects of reliability are covered over periods of 2 to 3 years. In particular, risks
flagged up by feedback from the year just passed are monitored. Audit conclusions
are presented to RTE's Executive Committee. Recommendations are then
formulated so as to improve the way in which identified risks are managed. The
initiatives undertaken based on these recommendations are detailed in an action
plan, the progress of which is monitored by the Reliability Audit all Department. A
report is submitted annually to RTE's Executive Committee and to the CSEA.
Three reliability audits were conducted in 2016 focusing on the following areas:
The way in which downgraded modes are handled on equipment,
The ring opening plan in the event of synchronism being lost,
The impact of renewable energies on the system's reliable operation.
Their conclusions indicate globally satisfactory operation of the power system in
terms of its reliability and formulate recommendations for improving its operation.
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Conclusion and outlook
The results obtained in 2016 indicate a globally satisfactory level of
operation by RTE in terms of reliability against a backdrop of increased – even
decentralised – renewable generation that is playing an increasingly important role
in the power system's reliability and stability (frequency, voltage, margin, etc.).
This requires increasingly flexible means.
However, 2016 saw two weather-related episodes – the period of summer heat in
mid-July which required closer surveillance of temperatures at RTE's substations
and the winter cold snap which coincided with a historically low availability of
nuclear generation means. These situations, which placed particular stress on the
system, were contained and even served as opportunities to put in place additional
management means (warning systems, load shedding, etc.) which should not hide
the risk of less favourable conditions being encountered over the next few years,
particularly in the event of periods of intense cold in future winters.
Tracking the SSEs over several years flags up any weak signals. These can be
analysed in more detail. And the effectiveness of any initiatives implemented to
increase operating reliability can be measured over time. Since 2013, the number
of SSEs has been stable (904 events in 2016 as opposed to 919 in 2013). Although
most of the SSEs recorded were equal to or less than A, we encountered and
analysed two level B SSEs and one level C SSE (based on a severity scale ranging
from 0 to F).
These satisfactory results are the fruit of work that has been done both internally
and externally with our partners over a number of years. They emphasise the fact
that ensuring system reliability is an ongoing task that is underpinned by corrective
actions, as well as scheduled initiatives implemented over time across an
extremely wide scope and involving expertise from a number of different areas.
All of these actions together address the major risk of there being a
blackout. They will help ensure the system's operational reliability in the
long term. This is RTE's fundamental task and assuming responsibility for
it benefits everyone in France and in Europe more widely.
The key issues that have been highlighted in this report involve the need to
continue with and bolster initiatives that have already been implemented at
various different levels over the next few years.
Ongoing vigilance to ensure reliability in the future.
In particular, this includes:
Internally at RTE:
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bolstering the implementation of support systems for operators,
continuing to improve the performance of tools for conducting analysis and
preparing for management,
consolidating the reliability of the IT system and the effectiveness of the
disaster recovery plans,
innovating by conducting experiments out in the field (substation of the
future), by making use of the new possibilities provided by digital
technologies, or by looking into new system management means (batteries,
etc.),
ensuring the effectiveness of companies' maintenance and renewal
initiatives in order to reduce faults on reliability-sensitive equipment
(switching devices, differential busbar protection devices, measuring
transformers, etc.).
In collaboration with our partners:
consolidating and adapting tools used to manage demand-supply balance
to ensure that they meet future requirements,
improving the quality of data shared at the interfaces, together with the
feedback loop,
expanding the assortment of market parties involved in order to increase
economic efficiency and flexibility in managing short-term demand-supply
balance (curtailment, asymmetrical frequency ancillary services, etc.),
consolidating mechanisms for systematically checking the commitments
and performance of stakeholders in order to ensure that reliability is
properly managed in new and changing configurations,
continuing discussions and tests with our partners who play a significant
role in ensuring the system's reliability (sharing data, reactive power of
generating units, controlling voltages at the interface between the
Transmission Grid and the Public Distribution Network, etc.).
And more specifically in Europe:
finalising technical analyses working alongside REE following the
oscillations encountered at the end of 2016,
making progress at French and European level in understanding and
controlling frequency biases, working on predicting them,
anticipating the coming into force of European grid codes in our tools and
methods,
ensuring the ability to share data between real-time platforms for all
stakeholders involved in reliability,
stepping up cooperation with system operators and the European
coordination centre during the cold snap at the start of 2017.
actively taking part in an analysis of the "winter packet".
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APPENDIX 1: Specialist glossary
Identifier Concept
Power system reliability
System reliability is defined as its ability to: - ensure the normal operation of the power system; - limit the number of incidents and prevent major incidents; - limit the consequences of major incidents when they do occur. Ensuring reliability is one of the key responsibilities entrusted to RTE by the law of 10 February in its capacity as owner of France’s transmission system.
Operating margins and security regulations
Security regulations prescribe: - a minimum margin of more than 1500 MW that can be mobilised in under 15
minutes; this figure is arrived at so that the loss of the largest coupled generating unit can be compensated for at any time;
- a minimum margin at the furthest deadline, the required volume of which
increases from a 15-minute timescale to one of several hours.
When these conditions are not met, depending on the circumstances, RTE issues a warning message on the Balance Mechanism or a "critical situation” S order.
Balancing Mechanism According to French law, generators must provide RTE with the powers that are technically available in order to ensure supply-demand balance. This is done via the Balancing Mechanism, which enables RTE to pool all the resources managed by the various stakeholders as a permanent and open system. At the same time,
stakeholders can maximise their demand response capacities and the flexibility of their generation. Based on price-volume bids, RTE performs the balancing required, inter-classifying proposals based on their price until the balance for which they are responsible is satisfied. There are provisions in place for power levels being too low: - for timescales of more than eight hours, RTE requests additional bids by sending
out a warning message; - for timescales of less than eight hours, a "downgraded mode" message enables
RTE to mobilise exceptional bids and resources not offered for balancing as well as any additional bids.
Primary and secondary frequency
control
Primary control is for automatically ensuring that balance is restored practically immediately after any contingencies affecting balance between generation and
consumption, and by all of the partners involved in the synchronous interconnection working together as one. Rules have been set by the ENTSO-E’s regional "continental Europe" group so that this action then maintains the frequency within defined limitations. Then, secondary control of the partner behind the disruption automatically cancels the frequency's residual discrepancy relative to the reference frequency, as well as discrepancies in relation to the scheduled cross-border schedules between the
various control zones.
ENTSO-E ENTSO-E (European Network of Transmission System Operators for Electricity), created at the end of 2008, has been the sole association of European TSOs since 1 July 2009. The ENTSO-E's role is to step up cooperation between TSOs in key areas, such as
in developing network codes about the technical aspects of the market and in the way in which it operates, coordination of the operation and development of the
European transport network, and research activity. In accordance with its statutes, the association's main decisions are taken by the General Assembly. An executive board is tasked with overall management and with preparing its strategic aims. Four main committees and their various sub-structures – the Market Committee, the System Development Committee, the
System Operations Committee, the Research and Development Committee and a legal analysis group – are responsible for the association's operational work. In order to technically coordinate the TSOs that are synchronously interconnected in Western Europe and assess their commitments to reliability (as defined in the 8 policies and agreed within the framework of the Multilateral Agreement signed by members of the former UCTE association), the System Operations Committee has
created an ad hoc regional subgroup – the Regional Group Continental Europe (RGCE). Consult: www.entsoe.eu
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Identifier Concept
Safety Telecommunications
This safety network is made up of a dedicated telecommunications infrastructure, most of which is owned and operated by RTE. It is used to convey all information (voice, data) needed for remote management.
Significant System Events (SSEs)
Pre-established criteria are used for detecting events from which lessons can be learned for the power system's reliability. These are grouped together in a "Significant System Event classification grid". The grid is used for classifying events based on their actual level of importance in terms of reliability. They are located on a seven-level severity scale. Level 0 is assigned to events which have the lowest consequences for reliability, but which should still be recorded nonetheless; levels A to F are for incidents of growing
severity up to a wide-ranging nationwide incident.
The method used to classify incidents involves assessing their severity based on two input types: - an input records the occurrence of concrete elementary events which affect the
way operation is carried out in a certain number of areas (distribution network, generation, system operation, management means, distribution);
- an input marks the extent to which the event has a damaging impact on the system.
Checking the performance of
generating facilities
Given the critical nature of the services provided by generating facilities, they may be subject to performance checks when they are connected up to the transmission grid. These checks are conducted such that they do not lead to significant increases in
work or in high costs for users or for RTE. Their purpose is to maintain the transmission grid's operating conditions so that everyone can benefit and the system's reliability is ensured. The idea is for performance to be checked at the facility's delivery point whenever such checks are enough for ensuring that performance levels are in compliance.
Checks are carried out to verify the way in which the generation units behave in relation to primary and secondary frequency control – power (statistical gain or
"droop", scheduled reserves, response times, etc.), as well as in relation to primary and secondary voltage control (provision of the contractual area in the Q/U diagrams, dynamic response, etc.).
Crisis organisation The ORTEC system (RTE’s crisis organisation plan) was introduced in the wake of the storms at the end of December 1999. It lays out the measures to take and
the organisational structure to be implemented at both national and regional levels when RTE declares a serious crisis. In addition to sourcing the necessary human resources and technical expertise, it provides for the implementation of communications initiatives for crisis management. Essentially, crisis units can be quickly mobilised across all of RTE's Units and at its Headquarters. In addition, grid incident response plans have been created for each of the regional
units. Their main aim is to ensure that cables which have sustained serious damage – and which are particularly important for the power system's reliability – can be restored in under five days.
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APPENDIX 2: Abbreviations used
ACR Agence de Conduite Régionale (Regional Management Agency)
ADN Automate de Défense Nord (northern defence automaton)
AMPRION German TSO
APGP Amélioration de la Performance par le Geste Professionnel (Improved Performance through
Professionalism)
CACM Capacity Allocation and Congestion Management
CCG Cycle Combiné Gaz (gas combined cycle)
CE Centre d’Exploitation (Operations Centre)
CNES Centre National d’Exploitation Système (National System Operating Centre)
CORESO CO-oRdination of Electricity System Operators
COrS’R Centre Opérationnel de Sécurité de RTE (RTE’s Operational Security Centre)
CSEA Comité de Surveillance Economique et des Audits (Economic Surveillance and Auditing
Committee)
CWE Central Western Europe
DCC Demand Connection Code
DTR Documentation Technique de Référence (Technical Reference Documentation)
ECCT Etudes Coordonnées Court Terme (Short-Term Coordinated Studies)
EH Electronic Highway
ELD Entreprise Locale de Distribution (Local Distribution Company)
END Energie Non Distribuée (Non-Distributed Power)
ENTSO-E European Network of Transmission System Operators for Electricity
ELIA Belgian TSO
EOD Equilibre Offre Demande (Supply/Demand Balance)
ESS Evénément Système Significatif (Significant System Event)
GdP Groupement de Postes (Group of Substations)
GIP Groupe d’Intervention Prioritaire (grid incident response plan)
GRD Gestionnaire de Réseau de Distribution (Distribution System Operator)
GRT Gestionnaire de Réseau de Transport (Transmission System Operator)
HDP Haute Densité de Production (High-Density Production)
HVDC High Voltage Direct Current link
ICS Incident Classification Scale
ICSI Institut pour une Culture de Sécurité Industrielle (France's industrial safety culture institute)
IDCF Intra-Day Congestion Forecast
IFA Interconnexion France-Angleterre (France-UK interconnection)
IGCC International Grid Control Cooperation
IMAP Intensité Maximale Admissible en Permanence (Maximum Permissible Permanent Current)
IPES Insertion des Productions Energies renouvelables intermittentes dans le Système électrique
(incorporation of intermittent renewable energy production into the power system)
IST Intensité de Surcharge Transitoire (Transient Overload Intensity)
LAD Localisation Automatique de Défaut (Automatic Fault Location)
LFCR Load Frequency Control and Regulation
LPM Loi de Programmation Militaire (Military Planning Act)
MA Mécanisme d’Ajustement (Balancing Mechanism)
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NEBEF Notification d’Echange de Blocs d’Effacement (Rules for participation of demand response in
energy markets)
NEMO Nominated Electricity Market Operator
NG National Grid, UK TSO
ORTEC Organisation de RTE en crise (RTE's crisis organisational structure)
RC Réserve complémentaire (Complementary reserve)
REE Spanish TSO
RfG Requirements for Generators
RGCE Regional Group for Continental Europe
ROC Regional Operation Centre
ROSE Réseau Optique de SEcurité (Optical Security Network)
RR Réserve Rapide (Quick Reserve) – Balancing Mechanism
RSFP Réglage Secondaire Fréquence Puissance (Secondary Load Frequency Control)
RST Réglage Secondaire de Tension (Secondary Voltage Control)
RSTN Réglage Secondaire de Tension réNové (Secondary Renovated Voltage Control)
RPD Réseau Public de Distribution (Distribution Grid)
RPT Réseau Public de Transport (Public Transmission Network)
RSCI Regional Security Cooperation Initiative
SAS Système d’Alerte et Sauvegarde (Safeguard Alarm System)
SIDRE Support Inter-Dipatchings Régionaux (Regional Inter-Control Centre Support)
SNC Système National de Conduite (National Management System)
SOGL System Operation GuideLine
SRC Système Régional de Conduite (Regional Management System)
STANWAY Project to replace the SRC
STATNETT Norwegian TSO
STS Système de Téléphonie de Sécurité (Safety Telephone System)
SWISSGRID Swiss TSO
S3REnR Schéma Régional de Raccordement au Réseau des Energies Renouvelables (Regional
Connection Program for Renewable Energies)
TCD Téléconduite (Remote Management)
TCE Temps de Coupure Equivalent (Equivalent Outage Time)
TCM Telecommunication
TCT Transformateur Condensateur de Tension (capacitor coupled voltage transformer)
TENNET-NL Dutch TSO
TERNA Italian TSO
Transnet BW German TSO
TSC TSO Security Cooperation
TSO Transmission System Operator
TURPE Tarif Utilisation Réseau Public d’Electricité (Public Transmission Network Usage Tariff)
TYNDP Ten-Year Network Development Plan