agenda - grtgaz€¦ · arc de dierrey november 2016 2016 low impact for customers. val de sâone...
TRANSCRIPT
Agenda
9.30am Welcome coffee
10.15am Network news o 2015 maintenance Overview
o 2016 maintenance schedule
o Maintenance European Benchmark & Maintenance Survey
o New on GRTgaz network : Arc de Dierrey & Dunkerque terminal
Thierry TROUVE’s speach
12.15pm : Lunch
14.00pm : Commercial newso Value your offer with the Biomethane !
o 2015 Striking facts and 2016 outlook
o New simplified offer at PITS
o North/South capacities sales until 2018
o French Market Outlook
16.00pm Afternoon snack & networking
17.00pm End
2
Agenda2015 maintenance overview
2016 maintenance schedule
Maintenance European benchmark & Survey on Works
Typology of works
4
Pigging / urgent pipe repair / pipe
repair
50%
Compression
Maintenance
27%
New project
20%
Pipe inspections
5
Pig
=> Capacityrestrictions (limited flow)
Urgent repairs
=> Capacityrestrictions (no flow)
Repairs
=> Capacityrestrictions (no flow)
Initial report // 4-6 weeks after the pig
Definitive report // 10 weeks after the end of pigging
First-inspection : after 10 years of useThen : Every 10 to 20 years
2015 maintenance OverviewAude Chevalier
Important maintenance
7
• Hauts de France I pipe (April)
• Centre pipe (April) + repair (September)
• Berry pipe (May) + repair (September)
3 major piggings
• Nord-Est pipe (August)
• Marches du Nord-Est pipe (June)
• Vendomois pipe (September)
• Rhône pipe (September)
4 major repairs
• Taisnières H automatic machine (April + September)
• Cruzy interconnection (May)
• Cuvilly interconnection (June)
3 majorupgrades
Montoir
Dunkirk Taisnières
Obergailbach
Oltingue
Fos
1
3
2
Minimizing the impact of maintenance
8
How?
When?
Why?
Where?
GRTgaz sometimes release capacity
As soon as GRTgaz has the information
Pipe inspection and repairs
Dunkirk release in June
(4 weeks)
Repairs planning update
Dunkirk & Taisnières H release in September
(3 weeks)
Flow configuration
(Terminal flow schedule)
North-to-South link
0
20
40
60
80
100
120
140
160
180
DUNKIRK [REC] OBERGAILBACH[REC]
OLTINGUE [DEL] TAISNIERES [REC]
3%13%
7%
12%
TWh
Summer 2015 - Subscribed Operational Firm Capacity
Available Capacity (GWh) Restrictions (GWh) Difference / Forecast
Firm capacities impact - PIR
9
+ 14%+ 3%
+ 3%
- 1%
2014
12%
2015
9%
Restriction rate
0
10
20
30
40
50
60
North-South [DEL]
1%
TWh
Summer 2015 - Subscribed Operational Firm Capacity
Available Capacity (GWh) Restrictions (GWh) Difference / Forecast
Firm capacities impact – North to South link
10
+ 1%
2014
2%
2015
1%
Restriction rate
0
5
10
15
20
25
30
35
40
North-West North-Atlantique South-Atlantique North-East South-East North B
6%9% 9%
3%
TWh
Summer 2015 - Subscribed Operational Firm Capacity
Available Capacity (GWh) Restrictions (GWh) Difference / Forecast
Firm capacities impact – Storage injection
11
- 3%
+ 7%
2014
4%
2015
5%
Restriction rate
0
10
20
30
40
50
60
70
80
90
FOS [REC] MONTOIR [REC]
8%3%
TWh
Summer 2015 - Subscribed Operational Firm Capacity
Available Capacity (GWh) Restrictions (GWh) Difference / Forecast
Firm capacities impact – LNG Terminal
12
4%
2014
5%
2015
5%
Restriction rate
About maintenance publication
13
Pu
blic
atio
nC
on
stru
ctio
n
Consultation of adjacent operators
August Y-1
NovemberY-1
Feb. Y
End of Feb. Y
D-60 WD-5 D-1 (3pm)
publication of
Guidelines by E-mail
Guidelines updates by E-
Consolidatedprogram
presented atShipper’s meeting
First Publicationon Trans@ctions
Restrictions Updates
Consideration of the major works
Consideration of all the works
Shipper survey on forecasts Survey update
publication of avaibilityof the North-South link *
* http://www.grtgaz.com/en/acces-direct/customer/shipper-trader/works
+
Expected value *+
2016 maintenance scheduleMiguel Antunes
AgendaNew projects, more capacities
Major maintenances
Summer capacity availability: 2016 vs 2015
Focus on Trading Region South (TRS)
New projects,more capacities
Modification ofMorelmaison
interconnection
Modification ofOltinguestation
Oltingue reverse flow project
17
Oltingue physicalreverse flow
October 20182016 impact
Oltingue closedfor 7 days
Cruzy reverse flow project
18
Modification ofCruzy
interconnection
Cruzy physicalreverse flow
2018
Modification ofSt Martin
interconnection
2016 impactCruzy closed for 3
days
Arc de Dierrey – Second part
19
Modification ofDierrey
interconnection
Modification ofVoisines
interconnection
Arc de DierreyNovember 2016
2016Low impact
for customers
Val de Sâone – Beginning of works
20
Modification ofPalleau
interconnection
Val de SâoneNovember 2018
2016 impactHigh North->South restrictions for 11
days
Major maintenances
Pigging that impacted flows
22
1• Arc Dierrey pipe - March
2• Gournay-Evry DN900 pipe – April/May
3• Flandres pipe - May
4• Taisnières-Cuvilly DN750 pipe – May
5• Morelmaison-Oltingue pipe – May
6• Guyenne DN800 pipe – May
7• Clipon-Pitgam pipe – September
8• Montoir-Nozay pipe x2 – October/November
Installation approvalRegulatory pigging
Other important works
23
Plateaux du Vexin pipe repairs (June)
Taisnières H regulationvalves maintenance
Nord Est pipe repairs(August/September)
Marches du Nord Est pipe repairs(August/September)
Centre pipe repairs(June)
Vendomois 900 pipe repairs (June)
Rhône pipe repairs(September)
Major West maintenances optimization
24
Weeks 22 to 2530th May – 24th June
Major East maintenances optimization
25
Weeks 36 to 385th– 24th September
Summer capacityavailability: 2016 vs 2015
Summer period 2016 vs 2015 comparisonEntry/Exit firm capacities at interconnection points
27
Points
Available firm capacities during Summer (TWh)
Tendency
2016 2015
Dunkerque REC 119 103 +15%
Taisnières H REC 117 105 +11%
Obergailbach REC 101 96 +5%
Total 337 304 +10%
Oltingue DEL 37 45 -17%
Taisnières B REC 47 47 =
Summer period 2016 vs 2015 comparisonNorth to South link firm capacity
28
Points
Available firm capacities during Summer (TWh)
Tendency
2016 2015
North to South link 55 54 +2%
Capacity maximum : 57,5 TWh
Summer period 2016 vs 2015 comparisonInjection capacities in storages
29
Points
Available firm capacities during Summer (TWh)
Tendency
2016 2015
North B DEL 24 23 +4%
North-East DEL 57 47 +21%
North-West DEL No restrictions 44
South-East DEL No restrictions 25
South-Atlantique DEL 37 39 -5%
North-Atlantique DEL 34 34 =
Summer period 2016 vs 2015 comparisonCapacity emission from LNG terminals
30
Points
Available Capacities during Summer (TWh)
Tendency
2016 2015
Montoir 76 76 =
Fos 72 75 -4%
Focus on Trading RegionSouth (TRS)
Trading Region South (TRS)In few words
Before 1st April 2015 From 1st April 2015
Contractual pointPIR Midi
Balancing ZoneTRS
In case of works:PIR Midi capacities
impact+
Fos
In case of works:TRS exit points impact (TIGF for a flowstream
North -> South)+
Fos
32
New balancing zone
Castillon
Cruzy
Trading Region South (TRS)Impact for Cruzy
33
• Restrictions on Fos
• Restrictions on Pirineos & Lussagnet
2015
• Restrictions on Fos (Egals to 2015)
2016
WorksNo flowrate
Trading Region South (TRS)Impact for Castillon
34
• Restrictions on Fos
• Restrictions on Pirineos& Lussagnet
2015
• Restrictions on Fos
• Restrictions on Pirineos& Lussagnet
2016
WorksNo flowrate
Maintenance europeanbenchmark & Survey on worksMiguel Antunes
Aude Chevalier
Guillaume Tuffigo
Maintenance europeanbenchmark Miguel Antunes
Aude Chevalier
Context
37
Maintenance European benchmark
Shipper’sdissatisfaction
Identifie and understand differences
Improvement
4 main subjects
38
Network Structure
Operational tool
Regulation and internal rules
Publication
Network structure
39
• 32 000Km of national pipes
• Severalsupplyingpoints
• Integratedstorages(Storengy)
• 5 000Km of national pipes
• Few supplyingpoints
• Central storage
• 4 200Km of national pipes
• Optimized for highflowrates and extremeconditions
• 7 500Km of national pipes
• Several LNG terminals
• Optimized for North -> South flowrates
Operational tool …
40
• LNG terminal and storagemanaged by differententities
• Flexibilitywith storage
• Flexibilitywith LNG terminal and storage
• Flexibilitywith LNG terminal
…limited for GRTgaz
Regulation and internal rules
41
• New pipe impliesinspection
• Nextinspection each 10 – 20 years
• New pipe impliesinspection
• Nextinspection each 10 years
• New pipe impliesinspection after 20 years
• Nextinspection each 7 - 15 years
• New pipe impliesinspection
• Nextinspection each 15 yearsat max
Regulation and internal rules
42
• Distance of pigging up to 200km
• Distance of piggingaround 40km
• Varyingdistance
• Varyingdistance
Substantial distance of pigging limitedmodulation
Various repair techniques
43
• Pressure constraints
• Lot of cutrepairs
• Repairs withpressure constraints
• Cut repairs
• Repairs withlow pressure constraints
• No cutrepairs
• Repairs withresininjection
Publication…
44
• All works withcapacityimpact
• Inter-operatorsagreements
• Inter-operatorsagreements
• If estimatedflow > availablecapacity
• No restriction
…too restrictive
Publication now and in the future
45
Survey on maintenanceGuillaume Tuffigo
Benchmark on the publication of the maintenance programme
March D-1Jan.August OD-5D-60Nov.
TIGF
1rst publication ENTSOG
Fluxys
National Grid
Publication plannings quite differents / Only GRTgaz publishes a maintenance program in August Y-1
Types of publications : Daily / Monthly
Pu
blic
atio
n
Informative publications
Binding publications
Consultation with the adjacent operators
GRTgaz
Survey results on the publications
48
Yes92 %
No8 %
Are these publications useful for You ?
Yes100 %
August November
Daily62%
Monthly38%
Granularity of these publications ?
Daily58 %
Monthly42 %
August September
Min/Max100%
Min only0%
Type of display for daily publications ?
Survey results on the publications
49
Survey results on the publications
Continuation of the publications in August and September
Daily granularity with CMNTt / CMXTt
NEW : expected value in the March publication
50
Benchmark on the Capacity releases
OD-5D-115h
D-60
GRTgaz : Possible releases
Other TSOs : Possible releases
GD
Capacity releases
52
Yes90%
No10%
Day Ahead release during the Week End ?
Yes80%
No20%
Intra Day release ?
GRTgaz will study the feasibility of these different releases
Yes *67%
No33%
Later Day Ahead release ?
* Until 16H30 or 18H or 00H or without limit
Benchmark and survey : Next Steps
End of the Survey postponed to the end of february in order to have more answers
At the next Working Group Structure before summer 2016 : Complete results of the Survey
Actions that GRTgaz plan to implement following the benchmark and the Survey results
Dunkirk LNG terminal & Arc de Dierrey projectJeanne Mascré
Bertrand Simon
Dunkirk LNG terminal Jeanne Mascré
A major project
• Dunkirk LNG terminal• Capacity: 13 billion m3 of gas
• Commercial deployment : September 2016
• Initiating of important projects for GRTgaz : Hauts de France II et Arcde Dierrey
• Direct link with non-odorised gas to the Belgium
56
Contractual illustration
A characteristic compared to the othersterminals: two outlets
13 octobre 201457
North zone
Belgium
Terminal
ALV
DK GNL
DKBSelling by Fluxys
ARC DE DIERREY PROJECTBertrand Simon – Project manager
Agenda
Issues and benefits
Find the best pipeline route
Our goals
The project today
Issues and benefits
To provide new source of arbitrage for the North zone
To prepare the GRTgaz’s North & South zones merger (2018)
To secure gas supply in the East in case of pick cold temperatures
or lack of gas
To create a large gas stock
European project (EU subsidy)
Find the best pipeline route
Around Arc de Dierrey, we find :
An urban area (Paris) and some wineyards
An huge natural environment : streams and woods
An important rural activities
An historic heritage
Find the best pipeline route
Find the best pipeline route
Find the best
pipeline route
Feedbacks
Studies
Security
Impacts
Agronomics & pedology
Communication
Open forum
People’srepresentatives
63
Avoid > Reduce > Compensate
Principles
Permitting within 24 months + 18 months for the construction of the first section
Engineering studies
Preservation of the area issues during the construction works
Purchasing processes
Sondages and archeological digs
Our goals
Unique project
3 years 1/2 :
Decision > Commisionning of the
first section
Permitting
Right of way agreement with
the owners
Open forum, impacts studies and communication : from 2008 to 2011
7 Permitting : 2012 & 2013
During 24 months
Design
Topographic surveys
Ground analysis
Infrastructure strength
Floor load capacity and ground protection
Engineering studies
According to the ground’s specificities (digging and treatments),
Flow issues throughout and after the construction,
Pipeline protection,
Crossing obstacles,
Drainage
Engineering studies
Environment :
Partnerships with National and Regional Nature Reserves
Deal with environmental associations and specialized agencies (studies and monitoring)
Environmental specialists
Preservation of the area issues
Birds : scare away techniques / preventives reapings / against-neasting
Bats : acoustics measures and sealing off trees cavities
Streams : filtration / decantation
Fishes and shellfishes : electrical fishing / transfert
Preservation of the area issues
Agronomics & pedology :
Agreement with the rural players (studies, monitoring)
Specialists and dedicated spokesperson
Local economy impacts :
Incitation contractual terms
Partnerships with Commerce and Industry Chambers and
employment agencies regarding subcontracting and recruitments
Quarterly reporting
A construction work monitored by
The regulation : DREAL
The environment : DDT, water policy, environment specialist...
Agronomics & pedology : farmer representatives
Security : safety management and health, security and environment specialists
The project today
B. Simon
The project today
B. Simon
On november 2015
The project today
B. Simon
On november 2015
Working progressWill be commissionned on
november 2016
GRTgaz 2016Catherine Brun
GRTgaz 2016 priorities
77
Customer Satisfaction
Energy Transition
An attractive French gas market
Customer Satisfaction
Shippers’ satisfaction:
Services: 95%
Commercial relation : 95%
Global perception: 97 %
Independency: 70% Code of conductGRTgaz is certified by the CRE
78
Energy Transition: GRTgaz strongly committedin a New Deal for Energy
79
An attractive French gas market: the single marketplace
CRE decision 2014, May 7 th
A single PEG in France
Merger of GRTgaz’ North and South balancing zones
Enabled by 2 major new infrastructures
80
A single marketplace meeting shippers’ expectations
Obergailbach
Dunkerque
Fos
Montoir
Oltingue
Taisnières
Station de compression
Site de stockage
Corridor OuestVal-de-Saône + Gascogne-Midi
Dk LNG
New infrastructures
Val de Saône project :• Looping of Burgundy pipeline
• Boosting the capacity of the compressor station at Etrez
• Adjusting the interconnections at Etrez, Palleau and Voisines
Gascogne-Midi project :• TIGF network : Partial looping of the Gascogne pipeline – Boosting the
capacity of the compressor station at Barbaira
• GRTgaz network : Adapting the Cruzy and Saint-Martin-de-Crau stations
to operate the Midi pipeline in a backhaul direction
Final Investment Decisions in 2015
Commissioning in november 2018
A single marketplace meeting shippers’ expectations
Consolidation works cover a series of flow configurations shared with the market
When the flow configurations depart from the initial assumptions, mechanisms have to be put into place
Obergailbach
Dunkerque
Fos
Montoir
Oltingue
Taisnières
Ouvrages saturés
Station de compression
Site de stockage
Dk LNG
GRTgaz’ proposition: Zefir project
83
GRTgaz’ proposition: Zefir project
A simple and competitive offerCo-constructed with you
based on:• regular and accurate information • firm and immediate mechanisms
To enable the market to propose the best solutions
84
Project Manager: Emmanuel Saron
Zefir Planning – Main Steps
85
2016 2017 2018
1st Nov
IT – Change Management -operational procedures
Final CRE Decision« Concertation Gaz »
Specifications
Studies and Design (Mechanisms to use ;Information to provide)
Exchanges and Works with othersInfrastructures Operators
IT – Change Management – operational procedures
Launch 1st step
Specifications
In order to start on November 2018, 1st : Final CRE decision in Q3-2017 Studies to start in Q1-2016 Co-construction with customers and « Concertation Gaz » in 2016&2017
1st step =« Super-Points
Travaux »
Launch
BIOMETHANEGreen gas to boost your offers!Julien SCHMIT
GRTgaz Biomethane Business Development
AgendaShort film on Chagny, 1st biomethane injection site into GRTgaz grid
Let’s start: what is biomethane?
French biomethane injection targets and nowadays situation
Biomethane value chain and benefits for gas suppliers
Let’s start: what is biomethane?
French resource to produce biogas via methanisation
89
2030 max usable potential: 56 TWh, ADEME (French Energy Agency) estimation
Household and community Food industry Agriculture
Manure (straw) Cereal straw Intermediate culture for energy purposes
Other crop residues
Manure(liquid)
Householdwaste
Wastewater treatment plant
Restaurants
Markets
French biomethane injection targets and nowadays situation
French long term renewable gas target
92
"In 2030, renewable energies represent 10% of gas
consumption"August 17, 2015 law
French short term biomethane target
93
2018
2023
1,7 TWh/y
6 to 8 TWh/y
"State tender as of 2016 to support biomethane injection"
Multiannual programming of energy (PPE)First orientations and actions 2016-2023
November 2015
Gas System Operators injection forecast
94
30 TWh/y (out of 56 TWh/y max potential)
12 TWh/y(out of 56 TWh/y max potential)
Nowadays
95
17 projects inject biomethane in France in many networks
~ 240 GWh/y of green gaspotential, end of 2015
GRTgaz projects
96
800 GWh/y max potential
Abandoned projects
Feasibility studies
Connection studies
ContractMore than 100 contacts
2016: 4 new contracts
Biomethane value chain
Biomethane value chain
Biomethane producer
Gas supplier
Gas consumer
DSOTSO
DSOTSO
Biomethane value chain
Biomethane producer
Gas supplier
Gas consumer
DSOTSO
DSOTSO
Value = biomethane sale over 15 years to a gas supplier to a minimum feed-in tariff secured by French state
100Injection power in Nm3/h
200 400 600
€/MWh
20
40
60
80
100
120
140
160
Depending on waste
Biomethane network injection MINIMUM feed-in tariffA gas supplier can pay more than the tariff for the biomethane
Biomethane value chain
Biomethane producer
Gas supplier
Gas consumer
DSOTSO
DSOTSO
Because of compensation mechanism, biomethane purchase is cheap for gas suppliers
102
Biomethane purchase price
–Monthly average Powernext Gas Spot Daily Average
(North or TRS)
=Compensation for gas suppliers concerned
Because of compensation mechanism, all French natural gas consumers pay a fee to support biomethane development
103
Biomethane development cost is socialized on French gas consumers
0,0153 €/MWh for 2015As of January 1, 2016, this contribution will be included in TICGN Tax.
Some customers may be exempted
A gas supplier can create guarantees of origin when it buys injected biomethane to a producer
https://gobiomethane.grdf.fr/
1 MWh of biomethane physically injected into a gas
network
GO=
1 guarantee of origin
Guarantee of origin register
Value = guarantees of origin speculation and exchanges on the register
Maximum ~1 year to create the guarantees after physical injection2016 decree possible evolution to max 3 months
Maximum 24 months after creation to value the guarantees
Exchanges of guarantees are possible on the register (=secondary market)
2016 decree possible evolution to open the exchanges to gas consumers
Value = renewable gas sale to a consumer thanks to guarantees of origin
106
OTC valuation price
Ex: 20 €/MWh
+ GO
x €/MWh
=
20 + x €/MWh
GO
Incentive to mobility
107
Mobility: gas supplier keeps 100% of guarantee valuation price
Other: 75% of guarantee valuation price goes back to compensation mechanism via fund manager, Caisse des Dépots
GO
x €/MWh
GO
x €/MWh
Value = green gas offer (marketing)
Natural gas offer
GO
Green gas offer
Biomethane value chain
Biomethane producer
Gas supplier
Gas consumer
DSOTSO
DSOTSO
Injection tariffs on gas networks are nil
Tariff at PITP (Transport Production Interface Point) = 0 € / MWh/d
Tariff doesn’t exist
TSOs
DSOs
Value = renewable gas shipping
A renewable gas thanks to guarantee of origin is sold to any consumer connected to
any gas network
Source : GRDF
1 guarantee of origin is created for 1 MWh of
physical injection in any gas network
GO
GRDF networks
Biomethane value chain
Biomethane producer
Gas supplier
Gas consumer
DSOTSO
DSOTSO
Cumulative values for gas consummers
• CO2 emissions reduction• Bet on future CO2 price• Reduced VAT for heating
networks• No need to change gas
installations to access renewable energy
• Image, communication• Marketing for green products
114
Biomethane is natural gas best friend
to maintain and develop gas attractiveness
More information
115
http://www.developpement-durable.gouv.fr/Pour-l-injection-dans-les-reseaux
http://www.injectionbiomethane.fr/
http://www.grtgaz.com/acces-direct/clients/producteur.html (for biomethane producers)
http://www.cre.fr/operateurs/service-public-du-gaz-ctss-et-contribution-biomethane/montant
http://www.smartgrids-cre.fr/
2015 Striking facts and 2016 outlookManuel Bonnier
2015 : Trading Region South
• Free access to TIGF
• A single market place
117
Quantities tradedSince Q3 2015/2014
+22%
2015 : Balancing
• + Alizés service
118
6h
7h
8h
9h
10h 11h 12h 13h 14h 15h
16h
17h
18h
19h
20h
21h
22h
23h
0h
1h
2h
3h
4h
5h
Projected Closing LinePack indicator
• October 1st : full implementation
2015 : Balancing – first feed back
119
• since 1st October 2015:
remaining imbalances
Shippers responsible and
incentivisedupgrade of marginal price ?depending on 2015/2016
Reinforcement of
intervention tools=> impact the Average Price
GRTgaz can’t be « balancing provider »
2015 : CAM
• + the North to South link
120
• November 1st : full implementation Within day
Obergailbach
Yearly
Quarterly
Monthly
Daily
Within Day*
Taisnières H
Yearly
Quarterly
Monthly
Daily
Within Day*
Taisnières B
Yearly
Quarterly
Monthly
Daily
Within Day
Oltingue
Yearly
Quarterly
Monthly
Daily
Within Day*
Starting from
November 2015
North South Link
Yearly
Quarterly
Monthly
Daily
Within Day
Alveringem
Yearly
Quarterly
Monthly
Daily
WithinDay*
2015 : what else ?
121
• NORTH to SOUTH: much lower spread, JTS goes on
• PIR Dunkerque : more entry capacity (monthly in winter):+20 GWh/d
• ALVERINGEM France to Belgium
• Ready for Dunkerque LNG terminal
PEG
ZTP
2016 : STORAGE
• Simple, faster booking CITS
• Optimal programation Single Nomination
EasySingle
April 1st
2016 : new LNG terminal in Dunkerque
• 13 Gm3 / year
• Access to• North Zone
• Belgium
New nominations Rules
124
IMPACT for WD Nomination
CAM : you will be able to nominate just after your auction
UBI on next cycles : no need for renomination (and… check !)
D-1 D
6am 10am 2pm 6pm 10pm 2am 6am2am10pm6pm2pm
1st WD 24 hours Product *
2nd WD window: 3am 3:30am 2nd WD 23 hours Product *
1st WD Window: 7pm 2:30am
Last WD window: 1am 1:30am
…Firm auction
Firm capacity
7am
NEWExtension window for nomination
Before :Last accepted value by GRTgaz
After April 1st :Last demand sent by the shipper
Current demand of the shipper
2016Design
Co-construction
2016 : North to South link
125
• NORTH to SOUTH…
Greater visibility
Easier booking
• …No more NORTH to SOUTH
+ For sale until GY2018+ Short term simplification+ JTS goes on
2016 : what else ?
126
Preparation for ATRT6PIR
Dunkerque
Maintenance
PEG => NCG
RegionalNetwork
CAM month
F IS1 S2 S3 S4
2016 : natural gas in the mix
127
• Useful
• Efficient
• On the « green way »
Preparation for ATRT6
Simplified offer at PITSNicolas LECLERC (Direction Commerciale)
Marie DEVILLERS (Direction Valorisation & Optimisation - Storengy)
Agenda1. An improvement of the offer
2. Capacity subscription
3. Capacity use
4. Changes in publications
An improvement of the offer at PITS
Both subscription and use of capacity at PITS improved from 1st April 2016 :
• More flexibility of subscription
• An optimization of the scheduling process at PITS
• A simpler offer : • Only one type of capacity at PITS
• Management of nominations & quantity scheduling handled only by Storengy
130
Capacity subscription
The “Capacité d’Interface Transport-Stockage”(CITS)
For all PITS, we create a new capacity type at PITS: the CITS• In place of both current firm & interruptible capacities
• The allocation of this capacity stays automatic and in line with your storage subscription
132
The capacity you subscribed is definitly yoursIt won’t depend anymore on other shippers subscription
The “Capacité d’Interface Transport-Stockage”(CITS)
One only capacity type at PITS improves the flexibility of subscription:
• Reduction of advance notice from 10 days to 5 working days before the start of your CITS/Storage product
• From 1st April on, CITS can:• Start & end any day of the month
• Last more than 1 day and less than 1 month
• An excess in capacity usage will be automatically billed as daily capacity
133
Example
• What you had before: • Equivalent in new system:
134
50
100
20
18
35
7
Shipper A Shipper B Shipper C
Firm Interruptible
68
135
27
Shipper A Shipper B Shipper C
CITS
GRTgaz neither changes the level of marketed capacity at each PITS nor the availability conditions from day to day
Capacity use
The Single Nomination with Storengy
Nominations & quantity scheduling will be:• Handled only by Storengy (via SAM), on the basis of the lowest of both operators’
Technical Capacities (called “CTM”)
• Transmitted to GRTgaz by Storengy
• Published in TRANS@ctions by GRTgaz & in SAM by Storengy
This process allows Storengy to reduce the duration of its scheduling cycles from 2 to 1 hour (except for the 1st cycle day-ahead)
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Caution : From 1st April 2016 onward, you shouldn’t nominate directly to GRTgaz anymore on PITS
Illustrations of scheduling cycles
SHIPPERNominations until H-2
on all Points Scheduled Quantities (H)
STORENGY Scheduling cycle
GRTgaz Scheduling cycle
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Matching
SHIPPERNominations until H-2
on all points except PITSNominations until H-1
On PITSScheduled Quantities (H)
STORENGY Scheduling cycle
GRTgaz Scheduling cycle
Time
For a better flexibility on storages, you will now have nominations on PITS until H-1 (instead of H-2) in your scheduling notice
Changes in TRANS@ctions publications
• Maintenance Schedule:• You will have access to the Minimum Technical Capacity (CTM) used by
Storengy to schedule quantities at PITS
• You will no longer have restriction rates (TRi & TRf) on PITS as the new capacity is scheduled by Storengy
• Your scheduling notice evolves:• Your scheduling notice (published at hour H) will now includes nominations
made until H-1 on PITS
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To continue
• For any further information, you will find “Find out more about…” notes in French & English at following URLs:• To find out more about the capacity offer at PITS from April 1st, 2016
• En savoir plus sur l’offre de capacités aux PITS au 1er avril 2016
• The Transmission Contract will be updated in accordance
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North South Link offeruntil 2018Jean-Damien LENOIR – Commercial Division / Marketing Department
AgendaContext
Yearly auctions in March 2016
Daily and Within day offer
Context
Context
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2015 : Come back of LNG in EuropeThe North South Link is less congested,From October 2015, unsold capacities are still available.
Nevertheless, still some days congested.
How to offer daily capacities? On which platform? How to offer long term capacities until merge (GY2018)?
Lot of discussion in Concertation Gaz in 2015CRE Consultation in December 2015 and Decision in February 2016
3 North South Link products :Firm, Interruptible, Market Coupling
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Firm Capacities
InterruptibleCapacities
270 GWh/d(+ 20 GWh/d in Winter)
150 GWh/dMarket
Coupling30 GWh/d
Level of Subscription until 2018 on February, 1st
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1/11/2018single PEG FranceToday
FirmCapacity
InterruptibleCapacity
420 GWh/d
270 GWh/d
Yearly auctionsin March 2016
Yearly auctions in March 2016on PRISMA
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Firm Capacity 10% of Available Capacities are kept aside for Quaterly then Monthly, Daily and Within Day
Auctions
Interruptible Capacity Interruptible capacities are commercialised when 95% of firm capacities are sold out Only yearly maturity No automatical conversion of interruptible capacities in firm
Bookablecapacity
(GWh/d)
oct.2016-sept.2017
oct.2017-sept.2018
Firm 46 30
Interruptible 39 25
% of available capacity
100% 50%
Bookablecapacity
(GWh/d)
oct.2016-sept.2017
oct.2017-sept.2018
oct.2018-sept.2019
Firm 46 30 83
Interruptible 39 25 58
% of available capacity
100% 50% 50%
Daily and Within-dayOffer
Availability of daily capacity
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F subscribed
F available
I subscribed
I available
270 GWh/d(290 GWh/din winter)
180 GWh/d
Market Coupling= 30 GWh/d max
Long TermSubscribed
Capacity As decided in Concertation Gaz (in Octobre 2015)
Good availability of long term subscribed interruptible capacities
Daily firm capacities available each day
Daily Firm Capacity= Long Term available
Capacity
How to book Daily and Within day capacities?
FirmCapacities
JTS
Peak Service
Day ahead PEGAS (Powernext)No reserve price
PrismaReserve price
= Regulated tarif
Within Day UBIRegulated tarif
In the continuity of winter 2015/2016 decisions
A smooth drive toward a single PEG (no reserve price)
Easy Within day capacities access thanks to UBI
French Market OutlookAlban Thomas
Yves Brullé
AgendaGas consumption on GRTgaz zones in 2015
Gas flows on GRTgaz network in 2015
GRTgaz gas demand scenarios 2015-2030
Avoided CO2 emissions
Gas consumption on GRTgaz zones in 2015
2015, one of the warmest years ever
(°C) Difference between normal temperature 1981-2010 and average temperature since 1921
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Extremely mild temperatures at the end of 2015
H1-2015: globally close to normal conditions, while H1-2014 was warm all alongthe period and H2-2013 was cold all along the period.
H2-2015: the end of the year was warm – climatic effect was mitigated by therising demand of gas power plants.
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Good level on Q1-2015
Low level on Q4-2015
Near normalon Q1-2015
Hoton Q4-2015
Average monthly temperatures Gross monthly consumption
Resumption of total gas consumption2015 vs 2014: +8.1% gross value and +3.4% climate corrected value
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0
50
100
150
200
250
300
350
400
450
500
2 005 2 006 2 007 2 008 2 009 2 010 2 011 2 012 2 013 2 014 2 015
Consommation totale brute (TWh/an) Consommation totale corrigée du climat (TWh/an)
TWh/year+8.1%gross value +3.4%
corrected value
Total gross consumption Total climate corrected consumption
Public distribution consumption is climate sensitive 2015 vs 2014: +6.6% gross value and -0.2% climate corrected value
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0
50
100
150
200
250
300
350
2 005 2 006 2 007 2 008 2 009 2 010 2 011 2 012 2 013 2 014 2 015
Consommation brute des DP (TWh/an) Consommation corrigée du climat des DP (TWh/an)
TWh/year +6.6%gross value -0.2%
corrected value
Public distribution gross consumption Public distribution climate corrected consumption
Growing consumption of industrial customers2015 vs 2014: +10.8%
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0
20
40
60
80
100
120
140
160
180
2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015
TWh/year
Recovery of gas demand for power generation. Stability of industrial activity over the year, rising at the end of the year.
GRTgaz industrial customers consumption
* Power generation includes gas fired power plants and main cogeneration facilities.
Averageon 10 years
125 TWh
Power Gen.*
+79.4%
Other Indus.
+0.15%
Total
+10.8%
Gas demand for power generation is strongly connected to declining gas prices
Gas prices are down from 22 €/MWh to 17 €/MWh between Q1-2015 and Q4-2015.
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Gas prices evolution in French gas market
Gas flows on GRTgaz network in 2015
TIGF
GRTgaz-Nord
GRTgaz-Sud
Pirineos (TIGF)
Montoir
Fos CavaouFos Tonkin
Dunkerque LNG
Dunkerque
Alveringem
TaisnièresH and B
Obergailbach
Oltingue
Many events on GRTgaz network in 2015
Development of physical capacities
Creation of the outlet Alveringem;
LNG terminal “Dunkerque LNG” is now connected to the network.
Interconnection Biriatou (TIGF) is operational since dec. 2015, with new capacities for Pirineos:
Spain to France (+32%).
France to Spain (+34%).
New market conditions
Trading Region South (TRS).
European network codes: market oriented balancing.
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Flow evolution 2015 vs 2014: North-South link was still highly demanded
• North-South link was still demanded at a high level:
Level of use 2015 (90%) vs 2014 (94%).
Saturated 126 days (2015) vs 244 days (2014).
• Transit to Spain is back to a normal level (2010-2014).
• Stability of the inlets by gas pipes in the North.
• LNG inlets continue to go down and are at their lowest level ever.
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-6 TWh-10 %
+1 TWh+13 %
+0 TWh+1 %
+19 TWh+11 %
-10 TWh-14 %
-10 TWh-5 %
-17 TWh-36 %
-13 TWh-10 %
Flow variations
Inlets / Outlets
2015 vs 2014
(TWh and %)
North-South link was highly demanded in 2015
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JTS: + 5 GWh/d
Effective technical capacity (GWh/d)
Effective North-SouthFlow (GWh/d)
Transit flows back to 5 year average
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TWh
/y Outlets to Spain
Outlets to Switzerland (Italy)
Stable imports: consumption growth is offset by transit flow slowdown
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TWh
/y Gas inlets (gas pipelines)
Inlets Montoir (LNG)
Inlets Fos (LNG)
LNG imports at their lowest level ever
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LNG imports to France
Inlets Montoir (LNG)Inlets Fos (LNG)
GW
h/y
GRTgaz gas demandscenarios 2015-2030
GRTgaz gas demand scenarios (TYS-2015)
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Realisticand
objective
Low
scenario
High
scenario
DGEC
scenario
Référence Moins 30 (LTE)Usages
DiversifiésAMS2
Energyefficiency
High Maximum High Maximum
Substitutionsby gas
Intermediate Low High -
Substitutionsby electricity
Intermediate High Low -
Gaz 2030(422 TWh 2014)
473TWh(493 TWh*)
449 TWh 558 TWh 375 TWh
(*) With strong development of gas vehicles
GRTgaz gas demand scenarios (TYS-2015)
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Annual gas demand (TWh)Reduction
of fossile gas
final demand2030 vs 2012
GRTgaz référence
-21%
Moins 30
-27%
Usages diversifiés
-10%
AMS2
-43%
Annual gas demand (TWh)
Avoided CO2 emissions
CO2 emissions avoided by substitution of coal by gas in power generation
171(1) Estimée à partir des données de puissance horaire par filières publiées par RTE.(2) Estimation à partir des quantités de gaz consommées pour la production d’électricité.
For the same quantity of electricity produced,twice less CO2 is emitted using gas instead ofcoal.
=> This production with gas instead of coal corresponds to 7 millions tonnes of CO2
avoided in 2015.
Gas fired and coal fired power generation in France in 20151
0
5
10
15
20
25
TWhe
0
5
10
15
20
25
100%Charbon
Gaz 70%Charbon 30%
100% Gaz
Mt
10,5 Mt avoided
Co
al
Co
al
Gas
Gas
Elec
tric
ity
7 Mt avoided
CO2 emissions
100%Gas
100% Coal
Gas 70%
Coal 30% mix2015
Electricity2
(from gas + coal)
In the world, to switch all the coal fired power plants to gas:• is consistent with 9 billions tonnes of CO2 avoided, compared with 50 billions tonnes CO2eq. world emissions
estimated for 2014.• would allow to reach 30 to 40% of the effort on CO2 emissions advised by GIEC to limit the global warming at 2°C.
In 2015, new gas uses enabled to avoid the emission of 490 000 tonnes of CO2
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Conversions from fuel-oil to gas 4,4 TWh of gas consumption are due to conversions of industrial customers in 2015.
They permitted to avoid 380 000 tonnes of CO2.
Biomethane injections 17 biomethane injection points in France:
• 1 GRTgaz, 1 rGDS, 1 TIGF, 14 GRDF
• 163 GWh of biomethane injected in 2015.
It corresponds to 34 000 tonnes of CO2 avoided in 2015.
Natural gas vehicles
76 000 tonnes of CO2 avoided in 2015 by fuelling 14 000 vehicles with natural gas instead of diesel.
Development of gas usesConversions + biomethane + NGV
490 000 tonnes of CO2 avoided
Main conclusions
Main conclusions
Gas consumption resumed despite warm conditions in 2015.
Gas demand for power generation in gas fired power plants has strongly increased, due tofavourable economic conditions.
Reinforcement of transmission capacities and rules harmonisation: Alveringem, Dunkerque LNG,Pirineos, Trading Region South, Market oriented balancing.
2015 was characterised by the lowest LNG imports to France ever, which entailed a still intensiveuse of the North-South link, despite transits to Spain and Italy back to 5 year average level.
New gas uses and biomethane permitted to avoid 490 000 tonnes of CO2 emissions in 2015.
GRTgaz gas demand scenarios are in line with the objectives of the energy transition policy in2030.
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Vision on GRTgaz network activity with GRTgaz+
At any moment, access to key-data relating to GRTgaz network.
Available on a large panel of smartphones.
To understand better, at any time, the gas transmission in GRTgaz zones in France.
An updated version will be delivered before next summer.
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