L-Gas Market
Conversion Review

Winter Report 2021
Task Force Monitoring L-Gas Market
Conversion

L-Gas Market Conversion Review – Winter Report 2021

Foreword
This is the third edition of the report monitoring the conversion of the low calorific gas (L-gas) markets in Belgium,
France, Germany, and the Netherlands in order to reduce demand for Groningen gas. This report looks back on
the market developments through the previous Gas Year (2019/20) and looks forward to the coming gas years
with regard to the observed and expected demand for Dutch L-gas and conversion progress of gas installations.
The current report provides an update on the progress of the conversion programs, with a special focus on the
impact of the Covid-19 induced lockdowns in 2020 and on planned conversions through the Gas Year 2021/22.
The estimated volume effect of the 2021 conversions (40 TWh) is the highest of all gas years of the conversion
programme, due to the particularly high conversion rates in Belgium and Germany.
The report is compiled by the International Energy Agency (IEA), the European Network of Transmission System
Operators for Gas (ENTSOG), Gasunie Transport Services (GTS), and the Netherlands Ministry of Economic Affairs
and Climate Policy (Min. EZK), under the umbrella of the Task Force Monitoring L-gas Market Conversion,
consisting of government representatives, representatives of transmission system operators (TSO’s) and energy
market regulators from Belgium, France, Germany, and the Netherlands, and an observer from the European
Commission. The activities of the Task Force are supported by the Benelux Secretariat. The report is published
semi-annually. The Netherlands will use this report to inform the Dutch Parliament on the progress of reducing
the demand for Groningen gas.

1

L-Gas Market Conversion Review – Winter Report 2021

Executive summary
The government of the Netherlands announced in March 2018 its decision to terminate natural gas production
from the Groningen field as soon as possible but not later than 2030, in order to guarantee safety in the area of
Groningen against the risk of earthquakes resulting from natural gas extraction.
The initial schedule for production phase-out - which aimed for termination in 2030 at the latest - was revised in
2019 following the adjusted advice of the State Supervision of the Mines after an earthquake occurred on 22 May
2019, with the objective of accelerating the termination by Gas Year1 (GY) 2022/23 for average weather
conditions. From mid-2022, gas from the Groningen field (Groningen gas) should only be needed in case of a
colder than average winter and in case of a severe disruption elsewhere in the L-gas system.
However the household appliances still need Groningen-gas in the Netherlands (max. Wobbe 44.4 MJ/m3) and
L-gas in Germany, Belgium, France (max Wobbe 46.5 MJ/m3). Without Groningen gas, so called “pseudo G-gas”
and “pseudo L-gas” is needed to secure the supply in the G- and L-gas market region.
Pseudo G-gas and pseudo L-gas can be principally produced as follows:
•

•

Pseudo G-gas:
o
nitrogen is added to high calorific gas (H-gas) in order to bring down the Wobbe-value until it
meets the upper Wobbe-limits of the G-gas specifications (44.4 MJ/m3); This gas quality is stored
in the Dutch G/L-gas storages
Pseudo L-gas:
o
nitrogen is added to high calorific gas (H-gas) in order to bring down the Wobbe-value until it meets
the upper Wobbe-limits of the L-gas specifications (46.5 MJ/m3);
o
enrichment: adding H-gas to pseudo G-gas until the upper Wobbe-limit of the L-gas specifications
(46.5 MJ/m3) is reached.

Whilst Groningen gas production has halved from 341.8 TWh (or 35 bcm) in GY 2014/15 to 170.9 TWh (or 17.5
bcm2) in GY 2018/19, the production of pseudo G/L-gas more than doubled during the same period of time. This
trend accelerated through the GY 2019/20, as Groningen gas production more than halved year-on-year, falling
by 86.72 TWh year-on-year, from 171.12 TWh in GY 2019 to 84.4 TWh. Consequently, the share of pseudo G/Lgas in total Dutch G/L-gas production grew from just above 30% in GY 2014/15 to close to 82% in GY 2019/20.
During the same period, the utilization rate of nitrogen blending facilities has increased steadily to average at
100% of firm capacity during the GY 2019/20. In the summer period (from May to September) pseudo G-gas is
used to inject into G-gas storages for usage through the heating season.
Pseudo G/L-gas is playing an increasingly important role in reducing Groningen gas production, with its share
expected to increase from 65% in GY 2018/2019 to close to 100% of G/L-gas produced in the Netherlands in GY
2022/23. Moreover, it is set to provide almost 95% of the upward production flexibility by GY 2022/23 necessary
to meet demand in a cold GY in the L-gas region. Nitrogen blending alone will account for over 87% of G/L-gas
produced in the Netherlands in GY 2022/23 and is expected to provide almost 85% of the upward production
flexibility necessary to meet demand in a cold GY.
Pseudo L-gas is exported to neighboring markets in Belgium, France and Germany, where it serves dedicated Lgas consumers – who will be converted to other sources of energy, most notably H-gas, as a result of the
Groningen phase out.
The gas infrastructure operators of Belgium, France and Germany have made arrangements to undertake
extensive conversion programs, mainly switching L-gas consumers to H-gas, this to reduce the L-gas supply from
the Netherlands: by GY 2029/30, imports of L-gas will be reduced to nearly zero.
The current report aims to monitor the progress in L-gas conversion in Belgium, France and Germany and the
activities in the Netherlands to reduce the consumption of (pseudo) G-gas, as well as the overall security of
supply developments within the G/L-gas market region. It provides the analysis needed by the Min. EZK to decide
on the allowed Groningen production and to meet the requirements of the resolution of the Dutch Parliament to
be informed twice a year about the progress in reducing the demand for Groningen gas.
Consumption of L-gas from the Netherlands decreased by 5% (or 24.1 TWh) from 483.1 TWh in the GY 2018/19
to 459 TWh in the GY 2019/20 in the L-gas region. This has been primarily driven by the continued implementation
of the market conversion programs in the respective L-gas markets, which reduced demand for L-gas. In GY
2018/19 conversion totaled to 15.76 TWh, with 13.5 TWh taking place in Germany, 1.37 TWh in Belgium, 0.888

1

A gas year (GY) starts on 1 October and ends on 30 September.
Volumetric data is expressed in Normal cubic meters (Nm 3), under reference conditions of temperature (0 °C) and pressure
(101.325 kPa).
2

2

L-Gas Market Conversion Review – Winter Report 2021
TWh in France and 0 in the Netherlands. In GY 2019/20 conversion totaled to 21.22 TWh, with 18.1 TWh taking
place in Germany, 1.92 TWh in Belgium, 1.2 TWh in France and 0 in the Netherlands.
Worth to note, that the implementation of nationwide Covid-19 induced lockdowns in the spring of 2020 had a
significant impact on natural gas demand worldwide and in Europe. In the L-gas region Dutch L-gas and H-gas
consumption fell by 19% (or 13.3 TWh) and 16% (or 34.2 TWh) year-on-year respectively during April and May.
Besides the lower economic and industrial activity due to the lockdowns, stronger solar power generation (up by
30% year-on-year) weighed on natural gas consumption during that period.
In the ten consecutive years, between GY 2019/20 and GY 2029/30, combined L-gas exports from the Netherlands
to Belgium, France and Germany are expected to be reduced at an average rate of approximately 10% per year.3
Consequently, L-gas demand met with imports from the Netherlands is expected to fall from 43.6 TWh in GY
2019/20 to 0 in Belgium, from 37.92 TWh to 0 in France and from 151.9 TWh to 0.3 TWh in Germany 4 by GY
2029/30 both in an average and cold GY.
To make the transition successful, the following criteria should be met:
•
•
•
•
•

the remaining L-gas demand is met with an adequate amount of L-gas supply, including pseudo L-gas
production, and sufficient transport capacity to ensure security of supply at any time;
H-gas supply to the Netherlands and the Northwest European markets needs continued monitoring as
it is used as feedstock to produce pseudo L-gas;
new nitrogen and conversion facilities come into operation without delays;
there are no significant delays in converting appliances from L- to H-gas;
the continuation of the Dutch TTF market structure (e.g. commercially one gas quality).

The Covid-19 induced lockdowns had only a minor impact on the overall schedule of the conversion programs. In
Germany, over 98% of the planned conversions have been executed in 2020. As foreseen in the Summer Report
of the Task Force, only an amount of 6,000 appliances (0.05 GW) out of 395.000 appliances have been
rescheduled from 2020 to 2021. In Belgium, due to the outbreak of the Covid-19 pandemic, delays in the works
carried out at TSO level and in the preparation activities at DSO level (amongst others the adaptation of household
pressure regulators) led to a postponement of the conversion to 1st of September instead of the 1st of June as
previously planned. However, this did not alter the initial conversion target for 2020. In France, the initial plan
for 2020 was the conversion of Dunkerque sector in October 2020 representing 42,000 customers and translating
into an annual consumption of 1 TWh under average weather conditions. The Dunkerque sector was successfully
converted on 27-28 October 2020 instead of 13 October as previously planned.
In 2021, over 900,000 of gas connections and appliances are expected to be converted in GY 2021/22 –the
highest number through the market conversion programme. The estimated volume effect of the 2021 conversions
(40 TWh) is the highest of all gas years, due to the particularly high conversion rates in in Belgium and Germany.
While the conversion areas are evenly distributed in terms of appliances per gas year for a large part of the
conversions, the resulting volume effect differs due to the regional distribution of industry and power plants with
a high gas consumption. Furthermore the high rates can be explained by optimization opportunities only possible
for specific areas in Belgium.
The analysis of the conversion programs, provided in Chapter 3 of the Report, shows an alignment with the
expected L-gas demand in each market and for each gas year.
To meet this declining L-gas demand against an even faster decreasing Groningen production, the Netherlands
will increase the production of pseudo L-gas, primarily by means of additional nitrogen blending.
Additional purchase of nitrogen allowed to expand the nitrogen blending capacity by 80,000 m3/h N2 at the
Wieringermeer conversion facility from 215,000 to 295,000 m3/h starting from 23rd December 2019. This
translated into an additional 48.9 TWh of pseudo L-gas production capability. Moreover, a new nitrogen plant at
Zuidbroek, planned to start operations from 1st of April 2022 with a capacity of 180,000 m3/h N2, will be able to
produce between 68 TWh to 97 TWh of additional pseudo L-gas. The outbreak of Covid-19 and consequent
lockdowns did up until now not have an impact on the commissioning date of the nitrogen plant as of September
2020.
However, the project slack has been exhausted. Uncertainty around the evolution of the Covid-19 and its
implications for the conversion planning and construction of the Zuidbroek facility remains a key risk. Due to the
current developments, there is a real risk of delay on the commissioning date of the Zuidbroek facility.

3

GTS (2017), Netwerk Ontwikkelingsplan 2017.
Please note that the remaining demand in the gas year 2029/30 (0.3 TWh / 100.000 kWh/h) is given by a regional grid in
Germany, that can only be supplied via the Netherlands (Haanrade / Thyssengas).
4

3

L-Gas Market Conversion Review – Winter Report 2021
The increase of H-gas conversion capacity via nitrogen blending in the Netherlands, the allowed Groningen
production and the market conversion from L-gas to H-gas in Germany, Belgium, France as well as in the
Netherlands will ensure the security of pseudo L-gas supply to consumers in all markets both in an average and
in a cold year.
GTS concluded in her advice of January 2021, that for the base case the minimum production from the Groningen
field is needed until GY 2025/2026. Based on the sensitivity analysis performed by GTS, a realistic bandwidth for
the closure of the Groningen field is between mid-2025 and mid-2028. The Government of the Netherlands wants
to close the Groningen field as quickly as possible. Alternatives for the Groningen field as a backup source for
security of supply are therefore being investigated. Anyhow, in the period 2021-2025 L-gas supply flexibility will
be entirely provided by the nitrogen blending facilities and the G-gas storages.
L-gas supply-demand balance projection in an average and cold year5 (GY 20/21-GY 29/30)

600
500

TWh

400
300
200
100
0
20/21
21/22
Groningen base
nitrogen flex

22/23

23/24
24/25
enrichment
Groningen flex

25/26
26/27
27/28
nitrogen blending
Demand (average)

28/29
29/30
enrichment flex
Demand (cold)

As a consequence of a declining domestic production and the subsequently growing need for H-gas to feed the
nitrogen facilities to deliver it as pseudo L-gas to L-gas consumers, the Netherlands almost doubled their H-gas
imports from 28.8 bcm (or 281.4 TWh) in GY 2013/14 to 57 bcm (or 556.9 TWh) in GY 2017/18. In fact, the
Netherlands became a net importer of natural gas in GY 2017/18 for the first time in the country’s history. Net
imports of natural gas rose by more than eight-fold since GY 2017/18 to reach 17.33 bcm in GY 2019/20 –
accounting for over 40% of the country’s total gas consumption.
Consequently, the security of L-gas supply is becoming intimately linked to the deliverability of H-gas into the
Netherlands.
Based on TYNDP2020 dataset, ENTSOG performed several additional disruption case calculations to investigate if
sufficient H-gas supply can be delivered to the northwest European markets in an average year and for high
demand situations. The results show that there is sufficient transport capacity during disruptions in an average
year. Compared to TYNDP2018 (disruptions) calculations the configuration at European level has improved thanks
to increased potential from suppliers (specifically extra LNG volume delivered to existing LNG terminals), new
import routes in Europe (see TYNDP2020), and the reduced gas demand in France and the UK. The planned
increase in capacity on the German/Dutch border raises the flexibility towards the Netherlands.
The L-Gas Market Conversion Monitoring Task Force will continue to monitor and assess the deliverability of Hgas supply to the Netherlands and the Northwest European markets served by L-gas.

5

In the case of Belgium and France, the demand profile for a cold GY has been calculated based on 1995-96 temperature
profile by GTS as stated in the Dutch Gas Act for the L-gas supply-demand balance of this Report. In the case of Belgium, the
preferred national approach is to consider the year 1962-63 as a cold year profile.The French regulation approach is requiring
to work with a 2% risk cold GY (using Lille weather data); leading to a demand profile national reference shared with the
French stakeholders, about 2% above the GTS’s figures.
.

4

L-Gas Market Conversion Review – Winter Report 2021

Key findings
1.

Based on the received data of the expected consumers demand for Dutch L-gas in Germany, France and
Belgium, and on the achieved results with regards to the market conversion in the three countries, GTS can
make a detailed assessment of the necessary volumes of L-gas for the coming year and the years after that.
As a result, a more precise assessment can be made of the necessary production from the Groningen field.

2.

Consumption of Dutch L-gas decreased 5% (or 24.1 TWh) from 483.1 TWh in the GY 2018/19 to 459 TWh in
the GY 2019/20 in the L-gas region. This has been primarily driven by the continued implementation of the
market conversion programs in the respective L-gas markets, which naturally reduced demand for L-gas. The
analysis of the conversion programs, provided in this Report, shows an alignment with the expected L-gas
demand in each market and for each Gas Year.

3.

Groningen gas production more than halved year-on-year, falling to 84.4 TWh in GY 2019/20. This has been
possible due to higher L-gas production via nitrogen blending, which increased by over 26% and drove up the
utilization rate of nitrogen blending facilities from an average of 90% through the GY 2018/19 to an average
100% of their firm capacity during the GY 2019/20. The share of pseudo L-gas accounted for close to 82% of
total Dutch L-gas production in GY 2019/20. Higher pseudo L-gas production was also possible with the
expansion of the nitrogen blending capacity at the Wieringermeer conversion facility, starting from 23 rd
December 2019. L-gas storage played a key role in allowing lower Groningen production, with net withdrawals
increasing by 13.14 TWh year-on-year from -6.32 TWh in GY 2018/19 (when injection outpaced withdrawals)
to 6.81 TWh in GY 2019/20. Net storage withdrawals met approximately one-fifth of the region’s L-gas demand.

4.

The Covid-19 induced lockdowns had only a minor impact on the overall schedule of the conversion programs.
In Germany, over 98% of the planned conversions have been executed. In Belgium, due to the outbreak of the
Covid-19 pandemic, delays in the works carried out at TSO level and in the activities at DSO level (amongst
others the adaptation of household pressure regulators) led to a postponement of the conversion to 1 st of
September from 1st of June as previously planned. However, this did not alter the initial conversion target for
2020. In France, the initial plan for 2020 was the conversion of Dunkerque sector, which has been completed
27-28 October 2020 instead of 13 October 2020. Uncertainty around the evolution of the Covid-19 and its
implications for the conversion planning and construction of the Zuidbroek facility remains a key risk. Due to
the current developments, there is a real risk of delay on the commissioning date of the Zuidbroek facility.

5.

In 2021, over 900,000 gas connections and appliances are expected to be converted in GY 2021/22 –the
highest number through the market conversion program. The estimated volume effect of the 2021 conversions
(40 TWh) is the highest of all gas years, due to the particularly high conversion rates in in Belgium and
Germany. The Task Force does not see any possibilities to further accelerate the conversion process. Currently,
all efforts are aiming at achieving the scheduled demand reduction for the coming years. In the ten consecutive
years, between GY 2019/20 and GY 2029/30, combined L-gas exports from the Netherlands to Belgium, France
and Germany are expected to be reduced to 0 at an average rate of approximately 10% per year.

6.

The increase of H-gas conversion capacity via nitrogen blending in the Netherlands and the market conversion
from L-gas to H-gas in Germany, Belgium and France as well as the activities in the Netherlands to reduce the
consumption of L-gas, will ensure the security of L-gas supply to consumers in all markets both in an average
and in cold year. This will allow to stop production from Groningen by GY 2022/23. For capacity reasons the
Groningen field may be needed for security of supply until approximately gas year 2025/2026. GTS concluded
in her advice of January 2021, that for the base case the minimum production from the Groningen field is
needed until GY 2025/2026. Based on the sensitivity analysis performed by GTS, a realistic bandwidth for the
closure of the Groningen field is between mid-2025 and mid-2028. The Government of the Netherlands wants
to close the Groningen field as quickly as possible. Alternatives for the Groningen field as a backup source for
security of supply are therefore being investigated.

7.

Due to the continuously increasing demand for H-gas for the conversion capacity, the Netherlands has become
a net importer of gas in GY 2017/18. Because of these developments, the security of supply of L-gas has
increasingly become more dependent on the flow of the increasing H-gas volumes into the Netherlands. Based
on TYNDP2020 dataset, ENTSOG performed several additional disruption case calculations to investigate if
sufficient H-gas supply can be delivered to the NW European markets in an average year and high demand
situations. The results show that there is sufficient transport capacity during disruptions in an average year.
Compared to TYNDP2018 (disruptions) calculations the configuration at European level has improved thanks
to increased potential from suppliers (specifically extra LNG volume delivered to existing LNG terminals), new
import routes in Europe (see TYNDP2020), and the reduced gas demand in France and the UK. The planned
increase in capacity on the German/Dutch border raises the flexibility towards the Netherlands.

5

L-Gas Market Conversion Review – Winter Report 2021

Contents
Foreword ................................................................................................................................................. 1
Executive summary ................................................................................................................................. 2
Key findings ......................................................................................................................................... 4
1. Introduction ......................................................................................................................................... 7
2. L-Gas demand ...................................................................................................................................... 8
3. L-gas market conversion volume....................................................................................................... 11
3.1 Germany ...................................................................................................................................... 11
3.2 France .......................................................................................................................................... 17
3.3 Belgium ........................................................................................................................................ 20
3.4 The Netherlands .......................................................................................................................... 22
4. L-gas production ................................................................................................................................ 23
5. Storage of L-gas ................................................................................................................................. 28
6. H-gas imports into the Netherlands .................................................................................................. 30
7. Conclusion & implications for Groningen production until 2029/30 ................................................ 32
Annex ..................................................................................................................................................... 34
Contributors .......................................................................................................................................... 44

6

L-Gas Market Conversion Review – Winter Report 2021

1. Introduction
The government of the Netherlands announced in March 2018 its decision to terminate natural gas production
from the Groningen field as soon as possible, in order to guarantee safety in the area of Groningen against the
risk of earthquakes resulting from natural gas extraction.
The initial schedule for production phase-out - which aimed for termination in 2030 at the latest - was revised in
2019 following the adjusted advice of the State Supervision of the Mines after an earthquake occurred on May
22, with the objective of accelerating the termination by Gas Year (GY) 2022/23 for average weather conditions.
From mid-2022, Groningen gas should only be needed in case of a colder than average winter and in case of a
severe disruption elsewhere in the L-gas system. Groningen gas has a notably lower calorific value compared to
the average European gas, which means it cannot simply be replaced by other domestic or imported sources.
These need to be converted, principally via nitrogen blending, to L-gas.
L-gas is consumed in the Netherlands and exported to neighboring markets in Belgium, France and Germany,
where it serves dedicated L-gas consumers – who will be converted to other sources of energy, most notably Hgas as a result of the Groningen phase-out. In fact, whilst over 90% of L-gas in Northwest Europe is produced in
the Netherlands, almost half of it is currently consumed in the three importing markets.
Hence, the decision to terminate Groningen production has consequences in terms of adaptation for the Dutch
domestic gas market, but also for export markets in Belgium, France and Germany. The four countries have been
working together since 2012 on the phasing-out of L-gas consumption, which was initially motivated by the
natural decline of the Groningen field. Belgium, France and Germany have developed and are implementing
concrete plans to have their consumers of L-gas converted to other sources of energy, most notably H-gas, by
2030.
The Dutch Parliament adopted a resolution which requires the Ministry of Economic Affairs and Climate Policy of
the Netherlands (Min. EZK) to report twice a year on concrete measures to reduce the demand for Groningen gas
and their foreseen impact6. In this report, explicit attention has to be given to measures within and with regard
to neighboring countries. Moreover, the claimed reductions should be substantiated with actual data and options
should be investigated to accelerate the reduction of the demand. In order to fulfil this requirement, the
Netherlands proposed to establish a Task Force on Gas Market Conversion Monitoring within the framework of
the Pentalateral Gas Platform. The authorities of Belgium, France and Germany concurred with this proposal.
The current report aims to monitor the progress in L-gas conversion in Belgium, France and Germany and the
activities in the Netherlands to reduce the consumption of L-gas, as well as the overall security of supply
developments within the low-calorific market region. It provides the analysis needed by the Min. EZK to decide
on the allowed Groningen production and to meet the requirements of the resolution of the Dutch Parliament. It
also creates a dedicated platform through the Task Force to further improve transparency and mutual
understanding among the involved countries, and enables to share options to accelerate the conversion, without
prejudice to national operators and end users. During the previous months, it has served as a platform to monitor
and discuss developments related to Covid-19 and its impact on the market conversion planning. The Netherlands
has used the information received during these meetings to inform their Parliament on 21st February, 8 April, on
19 June and most recently on 21 September 2020.
The current report provides an update on the progress of the conversion programs, with a special focus on the
impact of the Covid-19 induced lockdowns in 2020 and on planned conversions through the GY 2021/22. Over
900,000 of gas connections and appliances are expected to be converted in GY 2021/22 –the highest number
through the market conversion program.
The estimated volume effect of the 2021 conversions (40 TWh) is the highest of all gas years, due to the
particularly high conversion rates in in Belgium and Germany.

6

The Parliament’s resolution followed the decision made by the Dutch Council of State on July 3, 2019, which annulled the Min.
EZK’s decision on the allowed Groningen production in the Gas Year 2018/19. The Council of State concluded that it was not
sufficiently motivated why the demand for Groningen gas could not be reduced faster than foreseen. The Council of State not
only referred to Dutch demand but also to exports. According to the Council of State it was not sufficiently clear what the Ministry
meant with his statement that he is in dialogue with neighboring countries to reduce their demand and what actions he undertakes
to accelerate the reduction of exports of Groningen gas.

7

L-Gas Market Conversion Review – Winter Report 2021

2. L-Gas demand7
2.1 Recent demand trends
The consumption of Dutch L-gas declined by 9.9% (or 50.5 TWh) in GY 2019/20 compared with GY 2017/18,
falling from 509.5 TWh to 459 TWh.
Following a drop of 5% year-on-year (y-o-y) in GY 2018/19, total consumption of Dutch L-gas declined by another
5% (24.1 TWh) from 483.1 TWh in the GY 2018/19 to 459 TWh in the GY 2019/20. The consumption of total Hgas (excluding volumes used for conversion and enrichment in the Netherlands) remained stable in the region,
decreased by 1.4% in GY 2019/20.
The main driving force behind lower L-gas consumption in GY 2019/20 has been the continued implementation
of the market conversion programs in the respective L-gas markets, which naturally reduced demand for L-gas.
In GY 2018/19 conversion totaled to 15.76 TWh, with 13.5 TWh taking place in Germany, 1.37 TWh in Belgium,
0.888 TWh in France and 0 in the Netherlands. In GY 2019/20 conversion totaled to 21.22 TWh, with 18.1 TWh
taking place in Germany, 1.92 TWh in Belgium, 1.2 TWh in France and 0 in the Netherlands.
Figure 2.1 Consumption of L-gas from the Netherlands in between GY 2017/18 and 2019/20 (TWh)

-10%

500
450
400
350

TWh

300
250
200
150
100
50
0
2017/2018
Netherlands

2018/2019
Germany

Belgium

2019/2020
France

It is important to highlight that market conversion volumes do not necessarily translate into the same amount of
L-gas consumption change as other demand side factors also have an influence on the overall L-gas demand.
There is particularly a strong correlation between the number of heating degree days (HDD) and L-gas
consumption, given its predominant use for space heating purposes.
The impact of climatological factors has been minor in GY 2019/20 as the number of wind-adjusted HDD was only
slightly lower (0.9%) compared to the previous GY based on the measurements by the Royal Netherlands
Meteorological Institute at the weather station De Bilt.8
Worth to note, that the implementation of nationwide lockdowns in the spring of 2020 had a significant impact
on natural gas demand worldwide and in Europe, including in the L-gas region, where Dutch L-gas and total Hgas consumption fell by 19% (or 13.3 TWh) and 16% (or 34.2 TWh) year-on-year respectively during April and
May. Besides the lower economic and industrial activity due to the lockdowns, stronger solar power generation
(up by 30% year-on-year) weighed on natural gas consumption during that period. A secondary and indirect
impact of the lockdowns was the downward pressure on gas prices, which averaged 28% below last year levels
through June and September. This together with recovering carbon prices, prompted an increase in gas-fired
power generation at the expense of coal-fired power plants primarily in Germany and the Netherlands where –
based on data sourced from ENTSO-E- it in increased by 16% and close to 12% respectively during that period.
This provided support both for H- and L-gas consumption.

7

Demand is an ex ante concept, referring to expected energy quantitied being consumed. Consumption is an ex post concept,
referring to energy quantities which have been already consumed.
8
For more detail regarding the climatological context, please refer to Annex VI of the current report.

8

L-Gas Market Conversion Review – Winter Report 2021
As shown in Figure 2.2 Germany accounted for over 48.6% of the decline in Dutch L-gas consumption through
the 2019/20 GY, followed by the Netherlands (28.4%), France (15.2%) and Belgium (7.8%). Regarding year-onyear comparisons, France recorded a reduction of 8.8%, Germany 7.2%, Belgium 4.1% and the Netherlands
2.9%.
Figure 2.2 Change in Dutch L-gas consumption in GY 2019/20 vs GY 2018/19 (TWh)

-5%

490
480

-6.8
483

470

-11.7

-1.9
-3.7

460

TWh

450

458.9

440
430
420
410
400
390
2018/19

Netherlands

Germany

Belgium

France

2019/20

L-gas is predominantly consumed in the residential and commercial sectors for space heating purposes.
Consequently, L-gas demand shows a significant seasonal profile, with over two-thirds of consumption occurring
through the heating season of the GY. As such, both monthly peak consumption and the annual demand swing9
is taken into account when considering the overall evolution of L-gas consumption.
Peak monthly consumption decreased by 16% (12 TWh) in the 2019/20 GY compared to the previous GY and
consequently the demand swing (represented by the arrows in Figure 2.3) decreased by 20% (11.5 TWh). This
has been largely driven by the climatological context and the more even distribution of HDDs through the 2019/20
heating season.
Figure 2.3 Dutch L-gas monthly consumption October 2018 – September 2020 (TWh)

80
70
60

TWh

50
40
30
20
10

Netherlands

9

Germany

Belgium

sep-20

aug-20

jul-20

jun-20

mei-20

apr-20

mrt-20

feb-20

jan-20

dec-19

nov-19

okt-19

sep-19

aug-19

jul-19

jun-19

mei-19

apr-19

mrt-19

feb-19

jan-19

dec-18

nov-18

okt-18

0

France

The difference between the highest and lowest monthly gas consumption in a GY.

9

L-Gas Market Conversion Review – Winter Report 2021
2.2 The expected annual demand for L-gas from the Netherlands until GY 2029/30
In the ten consecutive years, between GY 2019/20 and GY 2029/30, combined L-gas exports from the Netherlands
to Belgium, France and Germany are expected to be gradually reduced at an average rate of approximately 10%
per year.10
As a consequence, L-gas demand met with imports from the Netherlands is expected to fall from 47.2 TWh in GY
2020/21 to 0 in Belgium, from 39.5 TWh to 0 in France and from 154.4 TWh to 0.3 TWh in Germany11 by GY
2029/30 both in an average and cold GY12.
Figure 2.4 Projected annual demand for Dutch L-gas (TWh)

L-gas demand in cold GYs

600

600

500

500

400

400

TWh

TWh

L-gas demand in average GYs

300

300

200

200

100

100

0

0

Netherlands

Germany

Belgium

France

Netherlands

Germany

Belgium

France

10

GTS (2017), Netwerk Ontwikkelingsplan 2017.
Please note that the remaining demand in the gas year 2029/30 (0.3 TWh / 100.000 kWh/h) is given by a regional grid in
Germany, that can only be supplied via the Netherlands (Haanrade / Thyssengas).
12
In the case of Belgium and France, the demand profile for a cold GY has been calculated based on 1995-96 temperature profile
by GTS as stated in the Dutch Gas Act for the L-gas supply-demand balance of this Report. In the case of Belgium, the preferred
national approach is to consider the year 1962-63 as a cold year profile.The French regulation approach is requiring to work with
a 2% risk cold GY (using Lille weather data); leading to a demand profile national reference shared with the French stakeholders,
about 2% above the GTS’s figures.The preferred national approach both in the case of Belgium and France are reflected in Figure
2.4 and in the tables 2.2 and 2.3 of the Annex.
11

10

L-Gas Market Conversion Review – Winter Report 2021

3. L-gas market conversion volume
The gas infrastructure operators of Belgium, France and Germany have made arrangements to undertake
extensive conversion programs, mainly switching L-gas consumers to H-gas, to reduce the L-gas supply from the
Netherlands: by the gas GY 2029/30, their imports of L-gas will be reduced to close to zero.
Both the realized number of gas installations or consumers that are converted and the corresponding volumes
are important to consider. In this report, countries supply data for each.
The current report provides an update on the progress of the conversion programs, with a special focus on the
impact of the Covid-19 induced lockdowns in 2020 and on planned conversions through the GY 2021/22. Over
900,000 gas connections and appliances are expected to be converted in GY 2021/22 –the highest number
through the market conversion programme.
The estimated volume effect of the 2021 conversions (40 TWh) is the highest of all gas years, due to the
particularly high conversion rates in in Belgium and Germany.
Figure 3.0 Volume effect of actual and planned conversions between GY 2019/20 and GY 2029/30
(TWh, based on average temperatures)

40
35
30

TWh

25
20
15
10
5
0
19/20

20/21

21/22

22/23

23/24

Germany

24/25

25/26

Belgium

France

26/27

27/28

28/29

29/30

3.1 Germany
Legislative changes, conversion costs and additional measures13
In order to implement the market conversion in Germany some 5.5 million gas appliances need a physical
adaptation. A sophisticated timetable for the conversion process was put into place in 2014 and legal changes
have been introduced. As of 2017, the Basic Energy Law (Energiewirtschaftsgesetz14) had been revised
substantially in order to serve as the basis for the market conversion from L- to H-gas. Article 19a of the Basic
Energy Law clarifies that the legal responsibility for the process lies with the transmission system operators and
that the necessary costs of adaptation of gas appliances are socialized (as an integral part of the gas grid fee).
Furthermore, the law lays down rules on partial reimbursement if customers buy a new gas appliance.
In addition, the Basic Energy Law was amended concerning access to the German L-gas grid in order not to
provide substantial amounts of L-gas to new customers.

13
14

For further details please refer to the Winter Report 2020 of the Task Force Monitoring L-Gas Market Conversion.
The text of the Basic Energy Law is accessible at: https://www.gesetze-im-internet.de/enwg_2005/

11

L-Gas Market Conversion Review – Winter Report 2021
The total costs for the conversion from L- to H-gas in Germany are estimated at approx. EUR 4 billion. The
conversion costs can be split into two different cost categories (1) costs for adapting the customers’ appliances
from L- to H-gas and (2) costs for grid expansion.
The German TSO GTG Nord had built a new blending facility at the Dutch border in order to reduce the need for
Groningen gas by up to 6 TWh a year, cf. below.

Conversions from 2015 to 201915
Approximately 300,000 appliances have been converted from L- to H-gas in the years 2015 – 2018. During the
years 2015 – 2018, several early conversions have been implemented. Furthermore, the German TSOs have
accelerated the planning for the consecutive years repeatedly. The conversions realized between 2015 and 2018
account for a capacity of 4.6 GWh/h and a yearly volume of 28 TWh. More than half of this volume accounted to
conversions ahead of schedule, which served to bring down demand for Groningen gas.
As these advanced changes had been made years before the due date, they continue to be a relief for the
Groningen production in the years to come.
In 2019, 10 areas with 319,000 appliances in total have been converted as planned. Conversion relates to a
capacity of 4 GWh/h and a volume of 13.5 TWh.

Conversions in 2020 and the impact of Covid-19
In 2020, 7 areas with 389,000 appliances have been converted. Conversion relates to a capacity of 5.15 GWh/h
and an estimated volume effect of approximately 18.1 TWh (average year).
The rapid spread of Covid-19 in Germany has only resulted in minor changes to the original conversion plans for
2020. As foreseen in the Summer Report of the Task Force Monitoring L-Gas Market Conversion, only an amount
of 6,000 appliances (0.05 GW) out of 395,000 appliances have been rescheduled from 2020 to 2021.
This, however, will not result in any changes in the import assumptions from the Netherlands in terms of volume
or capacity due to the limited size of the conversion area.
It is important to highlight that the technical regulation for the conversion from L- to H-Gas in Germany requires
multiple customer contacts between service technicians and the owners of the respective household device. First,
an assessment of the natural gas device is performed on site to ensure technical feasibility, planning of the
technical adjustment date and spare part logistics. The assessment of the device often takes place more than
one year ahead of the physical conversion date. Second, the actual technical adaption takes place either before
or after the device is physically supplied with H-gas. Third, 10% of the converted devices are checked again for
quality assurance purposes.
Performing these multiple customer contacts in a limited time schedule was significantly hindered by Covid-19
and its surrounding effects, in particular during the first wave. The Covid-19 pandemic meant that all parties
involved were facing challenges previously unknown.
In particular, these included the reduction or temporary suspension of assessment and adjustment work (causes
including those refusing entry), guaranteeing the full availability of conversion service providers, the
implementation of special hygiene protocols and providing the customers concerned with comprehensive
information.
Temporary delays that have accumulated during the first wave of Covid-19 in spring 2020 have mainly been
compensated during summer 2020. Further compensation has been achieved by conducting conversion steps
later in the year than originally planned, despite higher risks for the involved end customers if their heating
installation should malfunction during the switchover process. The last conversion steps in Germany for the year
2020 have successfully been conducted by November 2020. The respective conversion areas are displayed in the
illustration below.

15

For further details please refer to the Winter Report 2020 of the Task Force Monitoring L-Gas Market Conversion.

12

L-Gas Market Conversion Review – Winter Report 2021
Map 3.1.1 Conversion areas in 2020

Conversion areas 2020

The second wave did not have an impact on the timely implementation of the last conversion steps in the year
2020, which took place during November 2020. DSOs however reported a rising number of households under
quarantine that could not be entered on the foreseen date, but not in a critical magnitude to stop or postpone
the latest conversion steps. The respective areas are now physically supplied with H-gas. The process of
technically adapting heating devices is still ongoing and will approximately last until end of 2020 / beginning of
2021. Possible delays in these works would therefore not lead to an increased demand of L-Gas, but to an
increased number of malfunctions and disconnections.
Table 3.1.1 provides a detailed status of the conversion areas in Germany and the respective delays caused by
Covid-19.

13

L-Gas Market Conversion Review – Winter Report 2021

Table 3.1.1 Market conversion in Germany in 2020
Area in the Gas NDP
2020-2030
(No on map)

TSO

Number of
appliances
(original
plan)

Number of
appliances
(realized)

38,000

Planned
technical
conversion
month
(original)
February–June

Planned
technical
conversion
month
(realized)
February–June

EWE-Zone part I (1)

GTG

50,000

EWE-Zone part I (1)

GTG

17,000

23,000

September–October

30,000

30,000

July

September–
November
July

Bremen/ Delmenhorst (2)

GUD

Bremen/ Delmenhorst (2)
East Hannover/ Wolfsburg (3)

GUD

22,000

22,000

September

September

GUD

5,000

5,000

March

March

East Hannover/ Wolfsburg (3)

GUD

34,000

34,000

April

May

East Hannover/ Wolfsburg (3)

GUD

27,000

27,000

June

June

East Hannover/ Wolfsburg (3)

GUD

8,000

8,000

September

September

East Hannover/ Wolfsburg* (3)

GUD

0

0

October

October

Teutoburger Wald 5 (4)

OGE (Nowega)

39,000

39,000

October

October

Aggertal pipeline (5)

OGE

4,000

4,000

April

August

Aggertal pipeline (5)

OGE

3,000

0

August

–

Aggertal pipeline (5)

OGE

–

3,000

–

September

Aggertal pipeline (5)

Thyssengas

0

0

April

April

Aggertal pipeline (5)

Thyssengas

5,000

5,000

April

August

Aggertal pipeline (5)

Thyssengas

10,000

15,000

June

September

Aggertal pipeline (5)

Thyssengas

9,000

20,000

August

November

Aggertal pipeline (5)

Thyssengas

16,000

0

October

–

Bonn (6)

OGE

21,000

21,000

March

March

Bonn (6)

OGE

4,000

4,000

June

July

Middle Hesse (7)

OGE

22,000

22,000

March

March

Middle Hesse (7)

OGE

20,000

20,000

April

April

Middle Hesse (7)

OGE

17,000

17,000

June

June

Middle Hesse (7)

OGE

16,000

16,000

July

July

Middle Hesse (7)

OGE

16,000

16,000

September

September

395,000

389,000

Total
*no distribution networks

Despite the difficult Covid-19 situation in spring 2020, the gas demand from the Netherlands will not deviate
against the assumptions already published in the Winter Report 2020. However, the challenge ahead will be to
manage the high numbers of conversions scheduled for the next years.
Moreover, it is important to highlight that as of December 2020, Covid-19 did not cause any delays for the planned
commissioning dates of the grid expansion projects in Germany required for the conversion from L- to H-gas.
GTG's blending facility at the Dutch border is not yet in operation, since it is not yet connected to the H-Gas
network of GTS. Delays are due to material, which is requested to have unusual specifications, being available
no earlier than January 2021. It is therefore expected that the blending facility will go into operation in Q2 2021.
Conversions in 202116
The major challenge for 2021 will be the significant increase of the number of appliances to be converted. The
total amount of 570,000 appliances is an increase of approximately 45% against 2020. The planned conversion
of 2021 relates to a capacity of 9.5 GWh/h and an estimated volume effect of 31.5 TWh (average year).
The estimated volume effect of the 2021 conversion is the highest effect of all gas years. While the conversion
areas are evenly distributed in terms of appliances per gas year, the resulting volume effect differs due to the

16

The German Network Development (NDP) plan also refers to calendar years for the appliances converted and gas years for
resulting gas demand. As conversion usually take place between March and (early) October, the difference is insignificant.

14

L-Gas Market Conversion Review – Winter Report 2021
regional distribution of industry and power plants with a high gas consumption. An above-average effect on
volume results in particular from the conversion area (15) “Rhineland”, and besides that also from the conversion
areas (13) “Middle Rhine” and (3) “East Hannover/ Wolfsburg”. The planned conversion areas in 2021 are
displayed in the illustration below.
Map 3.1.2 Conversion areas in 2021

Conversion areas 2021

Due to the unclear development of Covid-19, additional risks may arise that could lead to delays. Possible risks
include workforce availability, spare parts availability or limited access to households for technicians to perform
adjustment works.
Due to the necessity to enter every single household 2 – 3 times for the conversion of one single appliance, the
future development of Covid-19 may be crucial to the success of the overall schedule for 2021. Adjustment works
in the respective households will start on a large scale in Q1/2021 typically 3 months before the actual conversion
date (switchover to physical supply with H-Gas), with a yet unclear Covid-19 situation.
Table 3.1.2 provides a detailed overview of the planned conversion areas in Germany in 2021.

15

L-Gas Market Conversion Review – Winter Report 2021
Table 3.1.2 Market conversion in Germany in 2021
Area in the Gas NDP
2020-2030
(No on map)
Aggertal pipeline (5)

TSO

Planned technical conversion
month

Thyssengas

Number of
appliances
(original plan)
14,000

Aggertal pipeline (5)

Thyssengas

17,000

June

Aggertal pipeline (5)

Thyssengas

11,000

August

Bergheim 1 (17)

Thyssengas

14,000

October

East Hannover/ Wolfsburg (3)

GUD

8,000

March

East Hannover/ Wolfsburg (3)

GUD

36,000

April

East Hannover/ Wolfsburg (3)

GUD

12,000

June

East Hannover/ Wolfsburg (3)

GUD

9,000

July

East Hannover/ Wolfsburg (3)

GUD

6,000

September

East Hannover/ Wolfsburg (3)

GUD

22,000

October

EWE-Zone part I (1)

GTG

6,000

November

EWE-Zone part II (8)

GTG

31,000

February-August

EWE-Zone part II (8)

GTG

3,000

October

North Bremen/ Osterholz Scharmbeck/
Bremerhaven/ Cuxhaven (9)
North Bremen/ Osterholz Scharmbeck/
Bremerhaven/ Cuxhaven (9)
North Bremen/ Osterholz Scharmbeck/
Bremerhaven/ Cuxhaven (9)
North Bremen/ Osterholz Scharmbeck/
Bremerhaven/ Cuxhaven (9)
North Bremen/ Osterholz Scharmbeck/
Bremerhaven/ Cuxhaven (9)
Unterlüß-Gockenholz* (10)

GUD

9,000

July

GUD

13,000

May

GUD

43,000

June

GUD

12,000

September

GUD

9,000

October

GUD

0

October

Verden (11)

GUD

13,000

October

Munster Gockenholz area (12)

Nowega

6,000

October

Middle Hesse (7)

OGE

6,000

March

Middle Hesse (7)

OGE

18,000

May

Middle Hesse (7)

OGE

27,000

June

Middle Hesse (7)

OGE

18,000

August

Middle Rhine (13)

OGE

45,000

April

Middle Rhine (13)

OGE

21,000

June

Middle Rhine (13)

OGE

8,000

May-August

Middle Rhine (13)

OGE

18,000

September

Middle Rhine (13)

OGE

15,000

October

Oberaden* (14)

OGE

0

June/ September

Oberbergisches Land (18)

Thyssengas

10,000

September

Rhineland (15)

OGE

22,000

July

Rhineland (15)

OGE

21,000

July

Rhineland (15)

Thyssengas

13,000

July

Rhineland (15)

OGE

0

September

Rhineland (15)

Thyssengas

0

July

Rhineland (15)

Thyssengas

0

September

Westerwald/ Sieg (16)

OGE

19,000

September

Westerwald/ Sieg (16)

OGE

16,000

July

Total

April

570,000

*no distribution networks

16

L-Gas Market Conversion Review – Winter Report 2021
Conversions until GY 2029/30
In Germany, over 3.7 million of gas appliances will need to be converted between GY 2021/22 and GY 2029/30,
translating into a total volume of 163.2 TWh.
Consequently, L-gas imports from the Netherlands to Germany are expected to fall to 0.3 TWh by GY 2029/30,
both in an average and a cold GY.17
Figure 3.1.1 Germany’s L-gas imports from the Netherlands (GY 2021/22-GY 2029/30) for average
and cold GYs (TWh)

160
140
120

TWh

100
80
60
40
20
0
21/22

22/23

23/24

24/25
25/26
Average
Cold

26/27

27/28

28/29

29/30

Update on conversion costs
The costs for adapting the customers appliances from L- to H-gas are reimbursed. The reimbursement only refers
to the adaption and not the replacement of appliances. Customers with installations that cannot be adapted from
L- to H-gas and have to be replaced are entitled to receive a lump sum of up to EUR 600 under certain
circumstances.
The actual costs for the adaption of appliances from the years 2016 – 2019 and the planned costs for the years
2020 – 2021 are displayed in the illustration below, altogether totaling to € 726 million.
Figure 3.1.2 Actual and planned costs for the adaption of appliances, 2016-21 (€ million)

Planned costs

Actual costs
250

224

200

179
141

€ million

150
95

100
59
50

28

0
2016

2017

2018

2019

2020

2021

17

Please note that the remaining demand in the gas year 2029/30 (0.3 TWh / 100.000 kWh/h) is given by a regional grid in
Germany, that can only be supplied via the Netherlands (Haanrade / Thyssengas).

17

L-Gas Market Conversion Review – Winter Report 2021
The respective costs are financed by a “market conversion levy” that is paid on top of the TSO transport tariffs.
Estimates for the cumulated market conversion levy until 2029 see costs of roughly € 2 billion.
Costs for grid expansion on TSO and DSO level are not included in the market conversion levy described above.
TSO costs for grid expansion related to L- to H-Gas conversion amount to another € 2 billion and are financed by
the regular transport fees.

3.2 France
Legislative changes and conversion costs18
In France almost 1.3 million of gas consumers have to be converted between GY 2019/20 and GY 2029/30,
translating into a total volume of 40.73 TWh/y.
Since 2015, the French legal and regulatory framework has been adapted to carry out the conversion of the Lgas network. The regulatory framework for conversion in France was adapted with a new decree dated 29 October
2020. In application of this new decree, L-gas network and storage operators updated the conversion plan which
was set up in 2016 taking into account mainly a few planning modifications and feedback from pilot phase.
Costs incurred by the TSO and the DSOs for the conversion of the L-gas networks are covered through gas
infrastructures tariffs and are estimated to amount to approximately € 800 million.
Conversions achieved in GY 2018/19 and GY 2019/20
A pilot phase has been decided to test the conversion process. During GY 2018/19 the conversion of the L-gas
network was carried out in the Doullens area (6,000 consumers converted on April 9, 2019, rural area with a
majority of individual housing) and the Gravelines area (10,000 consumers converted on September 17, 2019,
urban area with collective housing).
During the GY 2019/20 the conversion program continued in the Grande-Synthe area with 19,000 consumers
converted on November 28, 2019.
Conversions in 2020 and the impact of Covid-19
The initial plan for 2020 was the conversion of Dunkerque sector in October 2020 representing 42,000 customers
and translating into an annual consumption of 1 TWh under average weather conditions.
The Dunkerque sector was successfully converted on 27-28 October 2020 instead of 13 October as previously
planned. This sector is number four in France, the biggest and last of the pilot phase.
Operations at consumers’ houses to check and adapt gas appliances started on 2nd March 2020, with an expected
rhythm of 20% of appliances per month from April until June. 2,000 of them were checked and adapted as of
mid-March (16/03) when the operations have been suspended due to Covid-19 outbreak.
The lockdown in France stopped the conversion activities by DSO in the sector of Dunkerque on 16 March. It is
important to note that the area concerned by the conversion program in France was classified as a red area with
respect to Covid-19, which means that it was a highly contaminated area.
From 16 March, conditions for resuming settings of gas appliances have been put in place by the DSO and its
implementation has been initiated with customers: a letter and a "health instructions" brochure were sent to
customers informing them of the resumption of the settings under specific conditions to guarantee their safety
and the safety of the workers. The letter invited them to contact the DSO to confirm their agreement. Local
officials and local press relayed these messages.
Settings of customers appliances resumed on 18 May starting with around 30 volunteer heating technicians. A
ramp-up took place in the following weeks and significant efforts were made to catch up with the accumulated
delay. Thanks to these efforts the Dunkerque sector conversion was successfully achieved on 27-28 October,
2020 instead of 13 October as previously planned.
On the TSO side the network modifications for the conversion of the Dunkerque sector were achieved by the end
of 2019 and therefore the Covid-19 crisis had no consequence on that part of the program. Preparation by GRTgaz
of the conversions planned in 2021 and further was launched in 2019 and continued in 2020. In particular, there
are two GRTgaz projects to be achieved in 2021. Even if there is delay with respect to the original planning, the
current commissioning dates of these two projects remain compatible with the conversions planned in 2021.

18

For further details please refer to the Winter Report 2020 of the Task Force Monitoring L-Gas Market Conversion.

18

L-Gas Market Conversion Review – Winter Report 2021
The status in France at the end of November 2020 is that the second wave of Covid-19 did not have any significant
impact on conversion activities because:
▪

The second wave in France occurred after the conversion of the Dunkerque sector on 27-28 October;

▪

Inventory activities for the sectors to be converted in 2021 were mostly achieved at the end of October
and they could be finalized at the end of November;

▪

Preparatory works on the transmission network were not suspended during the second lockdown in
November.

Conversions in GY 2020/2021
The plan for 2021 is the conversion of Calais and Saint-Omer sectors in September and October 2021 representing
a total annual consumption of 1.2 TWh under average weather conditions. Preparation works for these
conversions are currently on track.
During the year 2020 preparation of 2021 and future conversions have been realized. Executed and planned
conversions are displayed in the illustration below.
Map 3.2.1 Market conversions in France in 2019 and 2020

Conversions until GY 2029/30
In France, over 1.26 million of gas consumers will need to be converted between GY 2021/22 and GY 2029/30,
translating into a total volume of 38.5 TWh/y.
Consequently, L-gas imports from the Netherlands to France are expected to fall to 0 by GY 2029/30, both in
an average and cold GY.

19

L-Gas Market Conversion Review – Winter Report 2021
Figure 3.2 France’s L-gas imports from the Netherlands (GY 2021/22-GY 2029/30) for average and
cold GYs

45
40
35

TWh

30
25
20
15
10
5
0
21/22

22/23

23/24

24/25

25/26

Average

26/27

27/28

28/29

29/30

Cold

3.3 Belgium
Conversions up to 2020 and costs19
In Belgium, the L- to H-gas conversion project continued in GY 2018/19, with the conversion of 15,000
connections on June 1, 2019, in Wallonia (municipalities of Gembloux, Hélécine, Incourt, Jodoigne, Lincent, OrpJauche, Perwez, Sombreffe). Another 20,000 connections were converted on Oct 1, 2019, in Flanders (Brasschaat,
Essen, Kalmthout, Wuustwezel). These conversions took place at junction points between the H- and the L-grids.
No particular issue is to be reported for this phase.
Each party is responsible for their own costs. The TSO and DSOs pass their costs on to the tariffs. Customers are
encouraged to have their devices checked for compatibility at the same time as the compulsory maintenance in
order to limit costs.
Conversions in 2020 and the impact of Covid-19
In 2020, some 129,761 connections were converted, translating into an annual consumption of 1.92 TWh under
average weather conditions. This has been partially enabled by an upgrade of the Winksele compression station
whereby H-gas from the natural gas transport backbone (West-East VTN) started to be injected into the L-gas
grid.
Due to the outbreak of the Covid-19 pandemic, delays in the works carried out at TSO level and in the activities
at DSO level (amongst others the adaptation of household pressure regulators) led to a postponement of the
conversion to 1st of September instead of the 1st of June as previously planned. However, this did not alter the
initial conversion target for 2020. In total, more than 50,000 connections were converted in the western part of
the Brussels-Capital Region (Berchem-Sainte-Agathe, Koekelberg, Molenbeek-Saint-Jean), more than 70,000
connections in Flanders (Dilbeek, Grimbergen, Kampenhout, Lennik, Machelen, Meise, Merchtem (Hamme),
Steenokkerzeel, Ternat, Vilvoorde, Wemmel, Zemst) and 6,000 connections in Wallonia (Soignies). The respective
conversion areas are displayed in the illustration below.

19

For further details please refer to the Winter Report 2020 of the Task Force Monitoring L-Gas Market Conversion.

20

L-Gas Market Conversion Review – Winter Report 2021
Map 3.3.1 Market conversion in Belgium in 2020

Conversions until GY 2029/30
In Belgium, over 1.5 million of gas connections have to be converted between GY 2020/21 and GY 2029/30,
translating into a total volume of 47.22 TWh/y.
Belgium’s conversion plan has been slightly revised, with the identification of an opportunity to optimize the
conversion of the Brussels Region Distribution Network. In the previous conversion planning, the Brussels Region
was converted in four years (2020 till 2023). The optimized conversion planning foresees a phased conversion
following the three commercial/physical zones of the Region (Aggregated Receiving Stations), whereby Brussels
is converted in three years (2020 till 2022).
The new planning requires a shift of some of the conversion activities from 2022 to 2021, and from 2023 to 2022.
It was the result of coordinated effort between the TSO Fluxys and the DSOs involved (Sibelga in Brussels, as
well as Fluvius in Flanders for the parts of its network which is supplied by the same TSO station as Sibelga).
Adaptions are required on the TSO network to facilitate this shift (notably enabling the simultaneous supply of
two types of gases – H and L – to Sibelga from one of the stations on the TSO network), and the DSOs had to
anticipate conversion activities and allocate resources accordingly. The optimization of the conversion planning
results in a small reduction of L-gas import needs between 2021 and 2023. The graph below shows the change
in the planning in terms of number of connections. From 2024 to the end, the conversion planning remains
unchanged.
Optimization of the conversion planning in Belgium

21

L-Gas Market Conversion Review – Winter Report 2021
In 2021, more than 300,000 connections are expected to be converted, translating into a total volume of 7.53
TWh under average weather conditions. As such, the expected volume effect of the 2021 conversion will be the
highest effect of all gas years.
This conversion will be partially enabled by the completion of a further tranche of work in the compressor station
of Winksele. More H gas will be supplied from Winksele in the direction of the Brussels Region and Flanders. In
Wallonia, several additional municipalities will be converted as well. The conversion is planned on 1st June 2021.
No significant issues related to the preparatory works have been reported at this stage. The planned conversion
areas in 2021 are displayed in the illustration below.
Map 3.3.2 Market conversion in Belgium in 2021

As a consequence to the market conversion, Belgium’s L-gas imports from the Netherlands are expected to fall
to 0 by GY 2029/30. However, the rising numbers of connections to be converted each year makes the L- to Hgas conversion a challenging program.
In the longer term, the Belgian market conversion has to take account of the remaining L-gas volumes required
for France.
Figure 3.3 Belgium’s L-gas imports from the Netherlands (GY 2020/21-GY 2029/30) for average
and cold GYs

60
50

TWh

40
30
20
10
0
20/21

21/22

22/23

23/24

24/25
Average

25/26
Cold

26/27

27/28

28/29

29/30

3.4 The Netherlands
Contrary to other L-gas consuming countries, the Netherlands has decided not to enter into a large scale
conversion operation. Instead, a new, large nitrogen facility is being built which, together with the already existing

22

L-Gas Market Conversion Review – Winter Report 2021
nitrogen facilities and underground storage facilities, will be able to provide enough L-gas (volume and capacity)
to meet Dutch demand in the years to come. For more details, please refer to Chapter 4 of the Report.
The legislative framework has however been adapted in order to limit future L-gas consumption. The Dutch Gas
Act has already been adapted to prevent future L-gas consumption growth by prohibiting the connection of newly
built houses and buildings to the gas grid. The new legislation concerning the conversion of industrial customers
(adopted on June 20, 2020) specifies that industrial customers consuming more than 100 million cubic meters
(mcm) annually are not allowed to use L-gas after October 2022. The plan is to convert 1 industrial consumer in
2021, 4 in 2022 and an additional 4 in 2023. As a consequence, Dutch demand for L-gas is expected to decrease
by approximately 3 bcm of annual consumption (~30 TWh), equating to the consumption of the nine largest
users20. To compensate for a part of the conversion costs of the relevant industrial customers, the Dutch
government will establish a compensation scheme.
In addition, steps are being taken to phase-out natural gas from the Dutch energy system between now and
2050. This follows the Paris Agreement on Climate Change and the Dutch Climate Agreement.

4. L-gas production
4.1 L-gas production in the Netherlands: recent trends
Following an increasing number of earthquakes in the province of Groningen, linked to the natural gas extraction
in the area, the Dutch authorities have imposed successive caps on Groningen’s gas production starting from
2014. Consequently, Groningen gas production has halved from 341.8 TWh (or 35 bcm) in GY 2014/15 to 171.1
TWh (or 17.5 bcm) in GY 2018/19. This trend accelerated through the GY 2019/20, as Groningen gas production
more than halved year-on-year, falling by 86.72 TWh year-on-year, from 171.12 TWh in GY 2019 to 84.4 TWh.
Groningen gas has a notably lower calorific value compared to the average European natural gas fields, which
means that it cannot simply be replaced by other (imported) natural gas sources. These need to be converted to
L-gas referred in the current report as “pseudo L-gas”. Pseudo L-gas can be produced either via nitrogen blending
or via enrichment.21
In line with the declining natural L-gas production from the Netherlands, the production of pseudo L-gas more
than doubled between GY 2014/15 and GY 2019/20 in order to meet the demand for L-gas. During the GY
2019/20, total pseudo L-gas production increased by 18% (or 56.95 TWh) year-on-year, from 316.15 TWh in GY
2018/19 to 373.1 TWh. Consequently, the share of pseudo L-gas in total Dutch L-gas production grew from just
above 30% in GY 2014/15 to close to 82% in GY 2019/20.
Figure 4.1 L-gas supply in the Netherlands between GY 2014/15 and GY 2019/20 (TWh)

600

90%
80%

500
400

60%

TWh

70%

50%

200

30%

300

40%

20%

100

10%

0

0%
2014/2015
2015/2016
2016/2017
2017/2018
Groningen
Enrichment
Nitrogen blending

2018/2019
2019/20
share of pseudo L-gas

It is important to highlight that this has been entirely driven by a higher L-gas production via nitrogen blending
increasing by 26.4% (or 59.2 TWh) while pseudo L-gas obtained via enrichment decreased by 2.4% (or 2.2 TWh)
20

In the current planning there are four sites where the conversion is expected to be delayed by several months. This should
have a limited impact on the gas production from the Groningen gas field as long as other measures remain on schedule.
21
In the process of nitrogen blending nitrogen is added to H-gas in order to bring down the Wobbe-value until it meets the upper
Wobbe-limits of the L-gas specifications. Enrichment refers to the process adding H-gas to Groningen-gas until the upper Wobbelimit of the L-gas specifications.

23

L-Gas Market Conversion Review – Winter Report 2021
following lower gas extraction from the Groningen field. As a consequence, the utilization rate of nitrogen blending
facilities has increased from an average of 90% through the GY 2018/19 to an average of 100% of firm capacity
during the GY 2019/20. The utilization rate has been above 100% through the summer months (from July to
September), indicating the use of back-up nitrogen capacity to produce higher volumes of pseudo L-gas, some
of which has been injected into storage for usage through the 2020/21 heating season.
Figure 4.2 Utilization rate of the firm capacity of nitrogen blending facilities (%)

100%
80%
60%
40%
20%
0%
2015/16

2016/17

2017/18

2018/19

2019/2020

Higher pseudo L-gas production has been made possible with the expansion of the nitrogen blending capacity by
80,000 m3/h N2 at the Wieringermeer conversion facility, starting operations on 23rd December 2019, slightly
before the planned start date. This has translated into an additional 48.9 TWh/year of pseudo L-gas production
capability.
Total nitrogen usage for pseudo L-gas production increased by 28.4% year-on-year, from 2.6 bcm during the GY
2018/19 to 3.35 bcm in the GY 2019/20.
Altogether, L-gas production in the Netherlands has fallen by 6.1% (or 29.77 TWh) year-on-year, from 487.3
TWh during the GY 2018/19 to 457.5 TWh in the GY 2019/20. As such, the decline in L-gas production has been
greater than the year-on-year reduction in L-gas consumption (-24.1 TWh) with the difference being compensated
by higher withdrawal from L-gas storage sites (see Chapter 5).

4.2 The impact of decreasing Groningen production on the Dutch gas market
It is important to highlight that reduced gas production in the Netherlands did not appear to have any impact on
the level of wholesale gas prices nor on the traded volumes on Dutch gas hub, the Title Transfer Facility (TTF).
In fact, gas prices on the TTF are reflective of broader regional and global supply-demand dynamics and as such
depend less on the levels of natural gas production in the Netherlands.
Natural gas prices on TTF averaged at €8.89/MWh through the GY 2019/20, their lowest price since TTF has been
launched in 2003. This has been partly driven by the particularly mild winter weather conditions both in Asia and
Europe, the substantial increase in liquefied natural gas (LNG) production capacity (mainly in the United States)
and the slowdown of natural gas demand growth both in Asia and Europe following the Covid-19 pandemic
outbreak and consequent lockdowns.
Under these market conditions, Europe –with its ample regasification and storage capacity- played a key role in
absorbing surplus LNG from the global gas market, with overall LNG imports into Europe22 rising by over 15 bcm
(approximately 170 TWh) year-on-year during the GY 2019/20. The LNG influx into Europe has been particularly
strong in the first half of the gas year, which in combination with lower demand provided downward pressure to
natural gas prices across European gas hub, including TTF.

22

The European Union, Turkey and the United Kingdom.

24

L-Gas Market Conversion Review – Winter Report 2021
Figure 4.2 TTF gas prices and traded volumes per heating seasons (2011/12-2019/20)

30

50000
45000

25

40000
35000
30000

15

25000

TWh

€/MWh

20

20000
10

15000
10000

5

5000
0

0
2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19 2019/20
Traded volumes

Price

During the same period of time, traded volumes on TTF expanded by 16.3 % year-on-year to over 42,960 TWh,
reinforcing TTF’s position as Europe’s leading gas hub. Importantly, the liquidity of the hub improved as well, as
certified by the improving churn ratio23, increasing from 70 in the GY 2018/19 to 83 in 2019/20.
4.3 Indication of the L-gas production in the Netherlands for the period GY 2019/20 – GY 2029/30
The Groningen production cap for the GY 2019/20 has been set at 11.8 bcm (or 114 TWh) for an average GY and
17 bcm (167 TWh) in a cold year. The initial target has been revised down in March 2020 by the Ministry of
Economic Affairs and Climate Policy, to 104.5 TWh (or 10.7 bcm) for an average GY and to 156 TWh (or 16 bcm)
for a cold GY. This was possible due to the high nitrogen utilization between October and December and the
expansion of the working gas volume of UGS Norg.
Figure 4.3 Indication of the L-gas production from Groningen in an average and cold gas year (GY
2020/21-2029/30)

160
140
120

TWh

100
80
60
40
20
0
20/21

21/22

22/23

23/24
24/25
Average year

25/26
Cold

26/27

27/28

28/29

29/30

It is currently being investigated what this means for the date by which the gas production from Groningen can
come to a full stop, i.e. no production even in the case of a cold GY. In this investigation two factors play a role:
volume and capacity/flexibility. For the analysis of this report a scenario elaborated by GTS, based on her advice
of January 2021 concerning the required Groningen production, has been used. From Figure 4.3 it becomes clear
that Groningen has to produce with an minimal flexible production until the GY 2025/26, to meet L-gas demand
in the case of eventual extreme cold GYs and in case of a severe disruption elsewhere in the L-gas system. The
Groningen field produces from GY 22/23 onwards at its minimum. This minimum production is necessary in order
to produce the required capacity in case of extreme cold and/or an outage in the L-gas system. GTS concluded
in her advice of January 2021, that for the base case the minimum production from the Groningen field is needed

23

The churn is the ratio between the traded volumes on a hub and the physical deliveries of the hub. A higher churn ratio suggests
a more liquid and developed hub.

25

L-Gas Market Conversion Review – Winter Report 2021
until GY 2025/2026. Based on the sensitivity analysis performed by GTS, a realistic timeframe for the closure of
the Groningen field is between mid-2025 and mid-2028.The Government of the Netherlands wants to close the
Groningen field as quickly as possible. Alternatives for the Groningen field as a backup source for security of
supply are being investigated.
To substitute the declining production from the Groningen field, the production of pseudo L-gas will further
increase, primarily by means of additional nitrogen blending with (imported) H-gas. In the GY 2022/23, pseudo
L-gas will account close to over 95% (or 365 TWh) of L-gas produced in the Netherlands and is set to provide
over 90% of the upward production flexibility necessary to meet Dutch L-gas demand in a cold GY in the L-gas
region. Nitrogen blending alone will account for close to 85% (or 321 TWh) of L-gas produced in the Netherlands
and expected to provide over 85% of the upward production flexibility necessary to meet demand in a cold GY24.
This will be supported by the new nitrogen plant at Zuidbroek, which is currently under construction and is planned
to start operations from 1st of April 2022 with a capacity of 180,000 m3/h N2 and able to produce between 68
TWh and 97 TWh of additional pseudo L-gas. The outbreak of Covid-19 and consequent lockdowns did not have
an impact on the commissioning date of the nitrogen plant. However all the slack in the project planning has
been exhausted and there is a real risk of a delay on the commissioning date of the nitrogen plant.

Figure 4.4 Indication of pseudo L-gas production during an average and cold gas year in the
Netherlands (GY 2020/21-2029/30)

450
400
350

TWh

300
250
200
150
100
50
0
20/21

21/22

22/23

nitrogen blending

23/24

24/25

enrichment

25/26

26/27

nitrogen flex

27/28

28/29

29/30

enrichment flex

4.4 Indication of the L-gas production outside Netherlands for the period GY 2019/20 – GY 2029/30
In Germany, L-gas production decreased by 15.6% (or 7.6 TWh) from 48.7 TWh in the GY 2018/19 to 41.1 TWh
in 2019/20. The overall decline in domestic L-gas production was in line with a lower L-gas consumption in
Germany and did not result in an increase of L-gas imports from the Netherlands (see Chapter 1).

24

In the case of Belgium and France, the demand profile for a cold GY has been calculated based on 1995-96 temperature
profile at the request of GTS. The preferred national approach is to consider the year 1962-63 as a cold year profile both in
Belgium and France.

26

L-Gas Market Conversion Review – Winter Report 2021
Figure 4.5 L-gas production in Germany in the GY 2018/19 and the GY 2019/20 (TWh)

-16%

50
45
40
35

TWh

30
25
20
15
10
5
0
2018/19

2019/20

In Germany, L-gas production is expected to decrease at an annual average rate of over 10% from 41.1 TWh in
GY 2019/20 to 13.7 TWh by GY 2029/30. There is one peak nitrogen/H-gas conversion facility in Germany, in
Rehden, supplying only limited volumes of converted L-gas.
In addition, the German TSO GTG Nord built a blending facility at the Dutch border. This facility allows for blending
Dutch Groningen gas with H-gas. GTS has finished their construction of the H-gas connection, however, GTG is
not yet connected to H-gas. GTG is still waiting for the necessary material as specified by the Dutch expert, which,
according to other Dutch partners, is required to have an unusual specification. The material is expected to be
available no earlier than January 2021. It is therefore anticipated that the blending facility will go into operation
in Q2 2021.
Once in operation, the blending facility allows an annual decrease of L-gas deliveries from the Netherlands of up
to 30% (5-6 TWh/y approx.) of the demand of GTG’s cross border point Oude Statenzijl. Thus, the facility is a
further relief to the Groningen production. The building costs of the facility and its operational costs are borne by
network users.
Figure 4.6 Indication of the L-gas production in Germany (GY 2020/21-2029/30) in TWh

40
35
30

TWh

25
20
15
10
5
0
20/21

21/22

22/23

23/24

24/25

25/26

26/27

27/28

28/29

29/30

There is no L-gas production in Belgium or France.
There is one nitrogen/H-gas blending facility in France. It is located at Loon Plage (near Dunkerque) and it was
designed for peak-load needs only. In 2021 this part of GRTgaz network will be converted to H-gas and this

27

L-Gas Market Conversion Review – Winter Report 2021
facility will be abandoned. There is one peak nitrogen/H-gas blending facility in Belgium, in Lillo, supplying only
limited volumes of converted L-gas.

5. Storage of L-gas
Natural gas storage plays a key role in meeting both seasonal and more short-term demand requirements,
providing additional flexibility to the gas system.
Given the high seasonal profile of L-gas demand (see Chapter 2), storage capacity is required to ensure the
adequate deliverability of L-gas supply.
It is important to note that in the past the Groningen field had a significant seasonal swing – the difference in
output during the heating and summer season - providing supply flexibility to the entire system. As shown on the
figure below, the production swing of Groningen has practically disappeared by 2015/16.
This in turn, is increasing the importance of L-gas storage in meeting both seasonal and short-demand variations.
Figure 5.1 Seasonal swing in Groningen gas production (2010/11-2019/20)

25

20

bcm

15

10

5

0

-5
2010/11

2011/12

2012/13

2013/14

2014/15

2015/16

2016/17

2017/18

2018/19

2019/20

It is important to highlight that in 2019/20, the seasonal swing turned into negative (-2 bcm). This has been
partly enabled by the higher pseudo L-gas output from nitrogen blending facilities on one hand and the greater
withdrawal rates from L-gas storages (primarily Norg).
5.1 Available storage volume of L-gas (in TWh) per country
Total L-gas storage capacity in Northwest Europe in GY 2019/20 amounted to 110 TWh, with a total withdrawal
capacity of 3,045 GWh/d. This represents an approximate 10% increase in working capacity compared with the
GY 2018/19 due to the expansion of the permit of the Norg facility in the Netherlands.
Most of L-gas storage is located in the Netherlands25 (75.3 TWh or 68%) and Germany (21 TWh or 19%). There
is one L-gas storage facility in France with a capacity of 13.4 TWh. L-gas storage in Germany is expected to
decrease in 2021, as the Lesum storage facility (with a working capacity of 1.44 TWh) will be converted to Hgas, whilst at the Huntorf storage site a capacity of 70 million m³, about 22% of its total storage capacity, are
planned to be converted in 2021 to store H-gas.. There is no L-gas storage in Belgium, which relies on L-gas
storages located in the Netherlands.
Over two-thirds of withdrawal capacity is concentrated in the Netherlands, followed by Germany (25.6%).
France’s Gournay storage facility accounts for 7% of L-gas withdrawal capacity in northwest Europe. For more
details on L-gas storage please refer to Annex 4 of the Report.

25

This includes three of the Epe storage sites, which are physically located in Germany, but are incorporated in the Dutch gas
network.

28

L-Gas Market Conversion Review – Winter Report 2021
It is important to highlight that Northwest Europe’s largest L-gas storage site, Norg, has been used to store
pseudo L-gas instead of gas coming from the Groningen field since 1st April 2020. This allows for a more optimal
utilization of nitrogen blending plants, as the facility can be filled with pseudo L-gas that the market cannot absorb
during the summer season (April-September) of the GY. It is currently investigated if the Grijpskerk storage (27.7
TWh working capacity) could be switched to store L-gas gas.
Figure 5.2 L-gas storage distribution by markets (TWh)

13

21

75

Netherlands*

Germany

France

*including Norg
5.2 The role of L-gas storage during the GY 2019/20
Storage played a key role in meeting L-gas demand through the GY 2019/2020, compensating for L-gas
production falling more rapidly (-6.1% or 29.77 TWh) than Dutch L-gas consumption (-5% or 24.1 TWh).
Storage withdrawals increased by 28.9% (or 21.9 TWh) year-on-year from 75.82 TWh in GY 2018/19 to 97.75
TWh in GY 2019/20 and outpaced the growth in injection which rose by 10.7% (or 8.8 TWh) from 82.14 TWh to
90.94 TWh. As such, net storage withdrawals increased by 13.14 TWh year-on-year from -6.32 TWh in GY
2018/19 (when injection outpaced withdrawals) to 6.81 TWh in GY 2019/20.

8
6
4
2

net withdrawals

TWh

Figure 5.3 L-gas storage net withdrawals in GY 2017/18 – GY 2019/20

-2
-4
-6

net injections

0

-8
2017/18

2018/19
Netherlands*

France

2019/20
Germany

*including Epe Eneco storage site located in Germany

29

L-Gas Market Conversion Review – Winter Report 2021
Worth to note, that the Norg storage facility26 in the Netherlands alone accounted for 80% of total net storage
withdrawals and for 54% of total storage supply through GY 2019/20. This is in line with GTS’ advice to utilize
working gas volumes to reduce Groningen gas production.
Gas supply from storage sites accounted for over 20% of total L-gas consumption27 through the 2019/20 heating
season, up from 15% during the same period in 2018/19.

6. H-gas imports into the Netherlands
As a consequence of its declining domestic production (see Chapter 5), the Netherlands almost doubled its natural
H-gas imports from 28.8 bcm in GY 2013/14 to 57 bcm in GY 2017/18 when it became a net importer of natural
gas for the first time in its history. Since GY 2017/18, the imports of the Netherlands remained stable (decreasing
by 0.3%), whilst exports and transit flows decreased by 28% between GY 2017/18 and GY 2019/20.
Consequently, net imports of natural gas rose by more than eight-fold since GY 2017/18 to reach 17.33 bcm in
GY 2019/20 –accounting for over 40% of the country’s total gas consumption, based on data sourced from the
electronic database of Statistics Netherlands.
Figure 6.1 Net natural gas imports of the Netherlands per gas year (2013/14-2019/20)

20

10

bcm

0

-10

-20

-30

-40
2013/14

2014/15

2015/16

2016/17

2017/18

2018/19

2019/20

It is important to note, that more than half of the imported H-gas is being converted to L-gas to supply L-gas
consumers both in the Netherlands and in the export markets.
Consequently, the security of L-gas supply is becoming intimately linked to the deliverability of H-gas into the
Netherlands.
The Netherlands has three main entry points. Norwegian natural gas is imported via the Emden terminal in
Germany which feeds into the Dutch gas grid and has an entry capacity of 352 TWh/y. Russian imports to the
Netherlands need to transit via Germany through the Bunde/Oude Statenzijl interconnection, with an entry
capacity of 184 TWh/y. LNG from the global gas market can be imported via the Gate LNG Terminal, which has
an annual send-out capacity of 168 TWh/y.
There are also two import interconnectors with Belgium: Zelzate and Zebra, with a combined entry capacity of
over 143 TWh/y. Zebra has recently been acquired by GTS and will be integrated into the GTS network.

26

Since the Norg storage is owned and operated by the same entity who owns and operates the Groningen field and has a direct
connection with the Groningen field, the Norg capacity and working volume are taken into account in the Groningen production
decisions (Dutch Mining Act, article 52c).
27
Including L-gas produced and consumed in Germany.

30

L-Gas Market Conversion Review – Winter Report 2021
Moreover, the BBL pipeline – connecting the Netherlands and the United Kingdom – became bidirectional on 1
July 2019, enabling natural gas imports into the Netherlands with an annual capacity of 61.32 TWh/y.
Data provided by ENTSOG indicates that total H-gas entry flows to the Netherlands rose by 1.8% (or 9 TWh)
year-on-year through the GY 2019/20. During the same period, exit H-gas flows from the Netherlands fell by
28.5% (or 31.3 TWh) year-on-year. This has been partly due to the lower exit flows primarily towards the United
Kingdom, with flows on the BBL pipeline falling by almost tenfold from above 21.6 TWh during the GY 2018/19
to 2.6 TWh through the GY 2019/20 due to higher LNG influx into the United Kingdom. Total net H-gas imports
to the Netherlands increased by 10% (or 40.3 TWh) year-on-year, largely driven by the higher feedgas needs of
nitrogen conversion facilities.
Figure 6.2 shows H-gas imports to the Netherlands by main entry points, with Emden and Bunde/Oude Statenzijl
accounting respectively for 36% and 28% of the total imports in GY 2019/20, whilst LNG imports via GATE for
17%, imports from Belgium for 15% and reverse flows via BBL to 5%.
Figure 6.2 Natural gas imports to the Netherlands by main entry points in the GY 2018/19 and GY
2019/20

28%

44%

2018/19

26%

36%

2019/20

0

100

200

Emden

Bunde

11%

15%

17%

300

Imports from Belgium

17%

5%

400
GATE

BBL

500

TWh

Figure 6.3 provides a comparison of the imported volumes and the utilization rates28 of the importing facilities
through the last two Gas Years.
LNG imports into the Netherlands edged up by 5.2% (or 4.42 TWh) year-on-year, increasing the utilization rate
of the Gate LNG terminal to 53% during the GY 2019/20 from 50% through the previous GY.
Figure 6.3 Natural gas imports to the Netherlands by main entry points and utilization rates in the
GY 2018/19 and GY 2019/20 *

250

90%
80%

200

70%
60%

150

TWh

50%
40%

100

30%
20%

50

10%
0

0%
GATE

Emden
2018/19

Bunde

Zebra

Zelzate

2019/20

2018/19

2019/20

BBL

* the columns represent imported volumes in TWh, the lines show the utilization rates of the given entry point

28

Actual import flows divided by firm capacity of the entry point (Lesser Of Rule applied).

31

L-Gas Market Conversion Review – Winter Report 2021
Higher LNG imports and lower transit flows towards the United Kingdom weighed on the entry flows via Emden,
with imports decreasing by almost 16% (or 35 TWh), driving down the utilization rate of Emden to 53% from
63% during the GY 2018/19.
Imports via the Bunde/Oude Statenzijl interconnection point with Germany decreased only slightly, by 6.3% (or
9 TWh), indicating a continued strong utilization rate of 73% through the GY 2019/20, down from 78% a year
earlier. Import flows from Belgium through Zebra and Zelzate rose by almost 40%, significantly increasing the
utilization rate of Zelzate from 40% to 62%.
Physical import flows via the BBL pipeline amounted to 26.5 TWh or 43% of the reverse capacity. This has been
largely supported by the strong LNG influx into the United Kingdom (up by 38.4% or 63.9 TWh year-on-year).
When considering these entry points, the annual spare import capacity of the Netherlands amounted to over 390
TWh through the GY 2019/20, comparing to approximately 469 TWh of gas consumption during that period of
the year.
Based on TYNDP2020 dataset, ENTSOG performed several additional disruption case calculations to investigate if
sufficient H-gas supply can be delivered to the NW European markets in an average winter. The results show that
there is sufficient transport capacity during disruptions in an average year and in high demand situations.
Compared to TYNDP2018 (disruptions) calculations the configuration at European level has improved thanks to
increased potential from suppliers (specifically extra LNG volume delivered to existing LNG terminals), new import
routes in Europe (see TYNDP2020), and the reduced gas demand in France and the UK. The planned increase in
capacity on the German/Dutch border raises the flexibility towards the Netherlands. In 2021, ENTSOG will perform
security of supply calculations in order to investigate the transport of gas in a cold winter. For more details on
the calculations see Annex VII.
The L-Gas Market Conversion Monitoring Task Force will continue to monitor and assess the deliverability of Hgas supply to the Netherlands and the Northwest European markets served by L-gas.

7. Conclusion & implications for Groningen production until 2029/30
The increase of H-gas conversion capacity via nitrogen blending in the Netherlands and the market conversion
from L-gas to H-gas in Germany, Belgium and France as well as the activities in the Netherlands to reduce the
consumption of L-gas, will ensure the security of L-gas supply to consumers in all markets both in an average
and in cold year.
Through the market conversion period, the role of enrichment will decline in line with the decreasing Groningen
production. Hence, nitrogen blending facilities will have an increasing role in meeting L-gas demand through the
next ten GYs.
Figure 7.1 L-gas supply-demand balance in an average year (GY 20/21-GY 29/30)

500
450
400
350

TWh

300
250
200
150
100
50
0
20/21

21/22
22/23
Groningen base

23/24
24/25
enrichment

25/26
26/27
27/28
28/29
29/30
nitrogen blending
Demand (average)

32

L-Gas Market Conversion Review – Winter Report 2021
GTS concluded in her advice of January 2021, that for the base case the minimum production from the Groningen
field is needed until GY 2025/2026. Based on the sensitivity analysis performed by GTS, a realistic bandwidth for
the closure of the Groningen field is between mid-2025 and mid-2028. In the consecutive GYs L-gas supply
flexibility will be entirely provided by L-gas enrichment and by the nitrogen blending facilities. The Government
of the Netherlands wants to close the Groningen field as quickly as possible. Alternatives for the Groningen field
as a backup source for security of supply are therefore being investigated.
Figure 7.2 L-gas supply-demand balance in a cold year29 (GY 20/21-GY 29/30)

600
500

TWh

400
300
200
100
0
20/21

21/22
22/23
Groningen base

23/24
24/25
enrichment

25/26
26/27
27/28
nitrogen blending

28/29
29/30
enrichment flex

The Covid-19 induced lockdowns had only a minor impact on the overall schedule of the conversion programs.
Uncertainty around the evolution of the Covid-19 and its implications for the conversion planning and construction
of the Zuidbroek facility remains a key risk. Due to the current developments, there is a real risk of delay on the
commissioning date of the Zuidbroek facility.

29

In the case of Belgium and France, the demand profile for a cold GY has been calculated based on 1995-96 temperature profile
by GTS as stated in the Dutch Gas Act for the L-gas supply-demand balance of this Report. In the case of Belgium, the preferred
national approach is to consider the year 1962-63 as a cold year profile.The French regulation approach is requiring to work with
a 2% risk cold GY (using Lille weather data); leading to a demand profile national reference shared with the French stakeholders,
about 2% above the GTS’s figures.

33

L-Gas Market Conversion Review – Winter Report 2021

Annex
Annex I: Consumers demand for L-gas from the Netherlands through the 2018/19 and
2019/20 heating seasons
1.1 Consumers demand for L-gas from the Netherlands30 in the GY 2018/2019 in TWh
Gas year 18/19

Germany

France

Belgium

Netherlands

October 2018
November 2018
December 2018
January 2019
February 2019
March 2019
April 2019
May 2019
June 2019
July 2019
August 2019
September 2019
Total 18/19

12.6
16.9
20.3
24.4
18.3
18.5
13.4
11.9
7.1
5.7
6.4
8.1
163.6

3.1
5.1
5.7
6.6
4.9
4.6
3.1
2.5
1.6
1.4
1.3
1.7
41.59

3.2
5.4
6.2
7.5
5.4
5.1
3.4
3.0
1.6
1.4
1.4
1.9
45.44

16.8
26.7
30.1
36.0
26.3
25.4
16.7
15.1
9.6
9.5
8.9
11.5
232.43

1.2 Consumers demand for L-gas from the Netherlands in the GY 2019/2020 in TWh
Gas year 19/20
October 2019
November 2019
December 2019
January 2020
February 2020
March 2020
April 2020
May 2020
June 2020
July 2020
August 2020
September 2020
Total 19/20

Germany
12.2
19.1
20.0
19.7
17.0
17.1
10.9
9.4
6.6
6.3
5.9
7.7
151.931

France
3.0
5.0
5.6
5.7
4.8
4.5
2.1
1.8
1.4
1.3
1.1
1.7
37.9

Belgium
3.4
5.5
6.2
6.3
5.6
5.3
2.8
2.3
1.6
1.5
1.4
1.8
43.6

Netherlands
18.3
26.7
30.0
30.8
27.8
25.9
14.4
12.1
9.5
9.7
9.2
11.3
225.6

30

For Germany and Belgium, this accounts for imports of L-gas from the Netherlands and not total domestic demand. For France,
this accounts for final consumers demand per month, not taking into account L-gas injections/withdrawals in/from Gournay
storage and L/H blending. For the Netherlands, it accounts for domestic demand.
31
The import figures above do not account for the import via the storage “NUON Epe Gasspeicher”. The injection for this
storage is only possible from the Netherlands, withdrawals are possible from Netherlands and Germany. In the gas year 18/19
the additional export from the Netherlands to Germany via the Nuon storage accounted for 0.48 TWh, which is reflected in
chapter 6.2 “Injected and withdrawn storage volume”.

34

L-Gas Market Conversion Review – Winter Report 2021
Annex II: Indication of the demand for L-gas from the Netherlands until GY 2029/30
2.1 Indication of the demand for L-gas from the Netherlands in Germany until GY 2029/30 (TWh)
Cold

Average

TWh

GWh/d

TWh

20/21

171.7

1032

154.4

21/22

135.1

917

121.1

22/23

116.9

802

104.7

23/24

96.1

686

85.8

24/25

76.9

574

68.5

25/26

55.9

458

51.4

26/27

42.8

343

39.4

27/28

29.7

228

27.3

28/29

11.1

115

10.2

29/30

0.3

2

0.3

32

2.2 Indication of the demand for L-gas from the Netherlands in Belgium until GY 2029/30 (TWh)
Cold33

Average

TWh

GWh/d

TWh

20/21

57.7

426.0

47.2

21/22

48.5

347.0

39.7

22/23

40.8

264.8

33.4

23/24

39.1

248.1

32.1

24/25

36.1

220.2

29.6

25/26

30.4

179.5

24.9

26/27

22.8

124.5

18.5

27/28

15.2

80.2

12.4

28/29

9.1

45.8

7.4

29/30

0.0

0.0

0.0

32

Please note that the remaining demand in the gas year 2029/30 (0.3 TWh / 100.000 kWh/h) is given by a regional grid in
Germany, that can only supplied via the Netherlands (Haanrade / Thyssengas).
33
In the case Belgium, the demand profile for a cold GY has been calculated based on 1995-96 temperature profile by GTS as
stated in the Dutch Gas Act for the L-gas supply-demand balance of this Report. The preferred national approach is to consider
the year 1962-63 as a cold year profile, which is reflected in Figure 2.4 and in the table 2.2 of the Annex.

35

L-Gas Market Conversion Review – Winter Report 2021
2.3 Indication of the consumers demand for L-gas from the Netherlands in France34 until GY 2029/30 (TWh)
Cold35

Average

TWh

GWh/d

TWh

20/21

42.2

361.9

39.5

21/22

40.8

349.7

38.2

22/23

37.4

313.9

35.1

23/24

29.6

236.8

27.7

24/25

22.4

184.8

20.9

25/26

16.6

127.9

15.4

26/27

9.9

61.0

9.3

27/28

4.1

14.0

3.9

28/29

0.8

0.0

0.7

29/30

0.0

0.0

0.0

2.4 Indication of the demand for L-gas in the Netherlands until GY 2029/30 (TWh)
Cold

Average

TWh

GWh/d

TWh

20/21

274.0

4558

236.4

21/22

266.8

4348

229.8

22/23

248.0

4101

212.0

23/24

229.8

3816

195.7

24/25

225.7

3610

192.1

25/26

222.3

3401

189.2

26/27

218.9

3200

186.3

27/28

215.5

2987

183.3

28/29

212.0

2795

180.4

29/30

208.6

2615

177.5

34

For France, all data are provided on the basis of the conversion plan which was updated in 2020 based on the results of the
experimental phase in 2018-2020
The expected demand for France does not take into account the quantity of L-gas blended in the H-gas network Moreover,
commercial blending may occur due to the oversize of the L-gas supply contract between Engie and GasTerra. Due to the unability
to forecast the L-gas excess volumes sold by Engie on the Dutch and Belgian markets and the unability to forecast the efficiency
of inter-TSO swaps, commercial blending of L-gas in the H-gas network could be anywhere between 0 and 20 TWh in 2021.
The above forecasts for peak daily demands (in GWh/d) correspond to final L-gas consumers in France and they can be supplied
both by Taisnières B (Belgium/France interconnection point) and Gournay storage (and if necessary with nitrogen/H-gas blending
facility at Loon Plage, only for 19/20 and 20/21 winters).
The above forecasts for peak daily and annual L-gas demands (in GWh/d and TWh) are based on an evaluation of peak daily and
annual demands for each geographical sector to be converted for each year of the conversion period. For each year residual Lgas demand is the sum of gas demand for geographical sectors which are not yet converted to H-gas according to the current
provisional conversion planning in France.
35
In the case France, the demand profile for a cold GY has been calculated based on 1995-96 temperature profile by GTS as
stated in the Dutch Gas Act for the L-gas supply-demand balance of this Report. The French regulation approach is requiring to
work with a 2% risk cold GY (using Lille weather data); leading to a demand profil national reference shared with the French
stakeholders, about 2% above the GTS’s figures. The preferred national approach is to consider the year 1962-63 as a cold
year profile, which is reflected in Figure 2.4 and in the table 2.3 of the Annex.

36

L-Gas Market Conversion Review – Winter Report 2021
Annex III: Expected market conversion volume until GY 2029/30
3.1 Expected market conversion volume in Germany until GY 2029/30 (TWh)
Gas year

Volume converted
[TWh]

Number of installations
[Thousands]

31.5
19.3
25.4
20.2
23.7
17.2
17.0
20.5
14.7
5.2

20/21
21/22
22/23
23/24
24/25
25/26
26/27
27/28
28/29
29/30

571
495
552
505
514
484
458
326
298
108

3.2 Expected market conversion volume in Belgium until GY 2029/30 (TWh)
Gas year

Volume converted
[TWh]

Number of
installations
[Thousands]

7.53
6.25
1.36
2.52
4.66
6.42
6.1
4.96
7.42
0

20/21
21/22
22/23
23/24
24/25
25/26
26/27
27/28
28/29
29/30

323.02
335.75
71.1
101.63
96.25
166.14
129.57
91.04
212.31
0

3.3 Expected market conversion volume in France until GY 2029/30 (TWh)
Gas year

Volume converted
[TWh]

20/21
21/22
22/23
23/24
24/25
25/26
26/27
27/28
28/29
29/30

1
1.2
4
9
5.5
5.3
6.4
4.9
2.2
0.0

Number of
connections
[Thousands]

42
54
122
177
212
279
197
183
37
0

37

L-Gas Market Conversion Review – Winter Report 2021
Annex IV: Indication of the L-gas production until GY 2029/30
4.1 Indication of the L-gas production in the Netherlands from Groningen until GY 2029/30 (TWh)

20/21
21/22
22/23
23/24
24/25
25/26
26/27
27/28
28/29
29/30

Cold
145.8
79.2
16.5
11.3
10.6
7.3
0
0
0
0

Average
94.2
38.6
14.2
10.4
10.2
7.1
0
0
0
0

4.2 Indication of the L-gas production in Germany until GY 2029/30 (TWh)

20/21
21/22
22/23
23/24
24/25
25/26
26/27
27/28
28/29
29/30

Cold
36
34
33
27
25
23
21
17
15
14

Average
36
34
33
27
25
23
21
17
15
14

38

L-Gas Market Conversion Review – Winter Report 2021
Annex V: L-gas storage in northwest Europe
5.1 Working gas volume and daily withdrawal capacity of L-gas storage sites in Germany, France and the
Netherlands in GY 2019/20

Working gas (TWh)
Germany
Lesum
Nüttermoor L-Gas
Speicherzone L-Gas (EWE)
Empelde
Epe L-Gas (innogy)
Epe L-Gas (UES)
France
Gournay
the Netherlands
EnergyStock
Norg (Langelo)
Alkmaar
Epe Nuon
Epe Eneco
Epe Innogy
Peakshaver

Withdrawal rate (GWh/d)

1.44
0.43
9.67
3.55
1.77
4.47

52
24
247
73
98
285

13.4

223.3

3
59.34
5
3
1
3
1

252
791
357
117
95
119
312

5.2 Net withdrawals (in TWh) of L-gas per country in GY 2018/19 and GY 2019/20

TWh
The Netherlands
France
Germany

2018/19

2019/20

-3
0.5
-3.8

6
0.4
0.4

39

L-Gas Market Conversion Review – Winter Report 2021
Annex VI: Climatological context
GTS will make an analysis of the climatological context in the L-gas region. GTS will use the temperature
measurements of the measurement station in De Bilt to determine this context. This will then be used to analyse
the difference between the expected demand in an average year and the realized demand using GTS’ degree day
method.
L-gas is predominantly used in the residential sector for space heating, therefore L-gas gas demand is strongly
correlated with the temperature and wind. This is also the reason why the allowed Groningen production is
determined by the number of degree days in a year. The definition of the degree days is given in the Dutch Gas
Act. As stated in the Dutch Gas Act, both the temperature and wind are measured at weather station the Bilt.
The number of degree days can be calculated by
D = Σ max[(14 – Teff),0]
Where:
D = the number of degree days
14 = heating limit (the so-called “stookgrens”)
Teff = daily average effective temperature
Teff = T – (V/1.5)
Where:
T = daily average temperature
V = daily average wind speed
In the 2019/20 Gas Year there were 2057 degree days (including leap day), slightly lower than the 2075 degree
days recorded during the 2018/19 Gas Year.

40

L-Gas Market Conversion Review – Winter Report 2021
Annex VII: ENTSOG simulations
The gas system connects most of European countries, ensuring the most efficient solution for transporting and
storing large amounts of energy over long periods and distances.
The resilience of the European gas system is dependent on the future development of the gas demand and the
gas supply. By building different and contrasted scenarios, ENTSOG make it possible to assess the infrastructure
needs for contrasted situations with the aim of encompassing all possible developments and delivering the most
comprehensive assessment of the European gas system.
ENTSOG has developed a modelling approach since 2010, based on a specific structure facing the need to consider
simultaneously network and market dimensions.
L-gas TF simulations
The simulations have been done using a base of TYNDP2020 simulations and some Security Of Supply
assumptions for the disruption cases and assess the infrastructure capacities to meet the H-gas demand for all
the needs: power, final demand and conversion to L-gas
Difference between TYNDP and SOS assumptions
For TYNDP, the network model represents the gas market within the geographical scope of the TYNDP and refers
both to the existing and planned infrastructure. Yearly and stressed gas demand data are based on different
scenarios all complying with European and national ambitions. It is a long-term assessment of the resilience of
Europe's gas infrastructure (20 years).
For Security Of Supply, the network model represents the gas infrastructure for the next winter season. Monthly
and stressed gas demand are provided by Transmission System Operators and are the coldest demand of the last
20 years. It’s a short term assessment of the resilience of Europe’s gas infrastructure, in stressed demand cases
and in some specific disruption cases.
Simulations input
The simulations have been done using the TYNDP2020 infrastructure, considering FID projects, the scenario gas
demand for the year 2020, 2025 and 2030 (figure 1 and 2) for which the gas demand in Netherlands is at the
maximum. The demand values in average winter used for TYNDP are lowest compare to SOS monthly gas demand
(+21% in average). And the 2-Week cold spell and peak day values in SOS are higher compare to TYNDP values
(+1.4 TWh/d in Peak day and + 3 TWh/d in 2-Week cold Spell) and the differences for Belgium, France,
Netherlands and Germany area are in the same order.
Figure 1 and 2: Comparison of SOS and TYNDP2020 gas demand in winter and in stressed period
(2-Week cold Spell and Peak day)

Winter demand comparison

2-week cold spell and peak stress
periods

30000

40
25000

35
30

15000

TWh/d

GWh/d

20000

10000

25
20
15
10

5000

5
0
oct

Nov

Dec

Jan

Feb

SOS- winter demand

Mar

0
SOS - 2- TYNDP - 2- SOS - Peak TYNDP WEEK Cold WEEK Cold
Day
Peak Day
Spell
Spell

TYNDP2020 - Average Winter 2020 demand
TYNDP2020 - Average Winter 2025 demand

UE

BE, FR, DE, NL, UK

TYNDP2020 - Average Winter 2030 demand

41

L-Gas Market Conversion Review – Winter Report 2021

Five specific disruption cases defined the last SOS report (table 1) are simulated for this exercise.

The simulations are done for the specific disruption cases above and for 3 different disruption periods:
-

2-Week Cold Spell: 15th of February to 28th of February

-

Peak day: 15th of February

-

2 Months: 1st of January to 28th of February

The simulations results are showing no risk of demand curtailment (gas demand are all satisfied) in all demand
periods and disruption cases.
To analyse the resilience of the infrastructure, we calculated the Remaining Flexibility for each country. The
remaining flexibility aims at capturing the extra supply flexibility a country can access through its infrastructure.
This flexibility is measured by the increase of demand an area can accommodate before an infrastructure or
supply limitation is reached somewhere in the European gas system. This indicator is calculated independently
area-by-area under stressful situations. The value is expressed as a percentage of the demand for a given area.
The higher the value, the better the resilience.
Concerning Netherlands, we can observe in the figures 3, 4 and 5 some slight changes in the remaining flexibility
in case of disruption cases compare to the NONE situation (without any disruptions) in all demand situations. The
worst case is Disruption case 9 (Disruption from Norway at Emden station).
The configuration at European level is better compared to last TYNDP and SOS (disruptions) thanks to increased
potential from suppliers, specifically for LNG, new import routes in Europe and the reduced gas demand in
countries in the Netherlands area.

42

L-Gas Market Conversion Review – Winter Report 2021
Figure 3: Remaining flexibility for Netherlands - 2020 - 2 months – 2 weeks – Peak day

1,2
1
0,8
0,6
0,4
0,2
0
2MONTHS

2W

DC

Sum of NONE 2020

Sum of Disruption7 2020

Sum of Disruption8 2020

Sum of Disruption9 2020

Sum of Disruption10 2020

Sum of Disruption13 2020

Figure 4: Remaining flexibility for Netherlands - 2025 - 2 months – 2 weeks – Peak day

1,2
1
0,8
0,6
0,4
0,2
0
2MONTHS

2W

DC

Sum of NONE 2025

Sum of Disruption7 2025

Sum of Disruption8 2025

Sum of Disruption9 2025

Sum of Disruption10 2025

Sum of Disruption13 2025

Figure 5: Remaining flexibility for Netherlands - 2030- 2 months – 2 weeks – Peak day

1,2
1
0,8
0,6
0,4
0,2
0
2MONTHS

2W

DC

Sum of NONE 2030

Sum of Disruption7 2030

Sum of Disruption8 2030

Sum of Disruption9 2030

Sum of Disruption10 2030

Sum of Disruption13 2030

43

L-Gas Market Conversion Review – Winter Report 2021

Contributors
This report is compiled by the International Energy Agency (IEA), the European Network of Transmission System
Operators for Gas (ENTSO-G), the Netherlands Ministry of Economic Affairs and Climate Policy and Gasunie
Transport Services (GTS) in close collaboration with:
Germany
Federal Ministry for Economic Affairs and Energy

Stefan Rolle, Andreas Krallmann

Federal Network Agency

Elena Albrecht, Andreas Muller

TSO: Open Grid Europe

Frank Harlacher

TSO: Gasunie Deutschland

Thorsten Brümmer

TSO: Thyssengas

Dr. Thomas Hügging

TSO: GTG Nord

Jann Keller, Jörg Saalfeld

TSO: Nowega

Sebastian Koch

France
Ministry for Ecological Transition

Etienne Denieul, Samir El Kanbi, Carole Mercier

Energy Regulatory Commission

Anne-Sophie Dessillons

TSO: GRTgaz

Emmanuel Freitag

Belgium
Federal Public Service Economy

Bernard Picron, Pierre Paladin
Benjamin Heylen

Commission for Electricity and Gas Regulation

Christian Cuijpers

TSO: Fluxys Belgium

Denis Bawin, Damien Vliegen

The Netherlands
Ministry of Economic Affairs and Climate Policy

Rodrigo Pinto Scholtbach (chairman), Wim van‘t
Hof, Sanne Remmerswaal, Ivar Letschert

Gasunie Transport Services

Jan Albert Laverman, Anne Spijkstra

Authority for Consumers & Markets

Anneke Francois

International Energy Agency (IEA)

Jean-Baptiste Dubreuil, Gergely Molnar

European Network of Transmission System
Operators for Gas (ENTSO-G)

Jacques Reberol, Hendrik Pollex

Secretariat-General of the Benelux Union

Geert Wegman

European Commission

Carmen-Magdalena Oprea

44