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EVENT URL: https://susret.hsup.hr/en/ PROGRAMME: https://susret.hsup.hr/en/programme/
JOIN US AT THE LEADING INTERNATIONAL GAS EVENT IN SOUTHEAST EUROPE!
Modeling Gas Challenges in Competitive Market
AGENDA:
• 5-7 minutes – Moderator: DAVOR MATIC, M.Sc., Vice-President of Croatian Gas Association (CGA):
Introduction from CGA moderator event and topic
________________________________________________________________________________________________________________________________
• 15 minutes – Speaker 1: TRACEY GRANGER, Lead Energy Market Analyst for Energy Exemplar –
Co-Optimisation of Electricity and Gas Markets
__________________________________________________________________________________________________________________________________
• 15 minutes – Speaker 2:Dr. MICHAEL THOMADAKIS, Partner, Energy Sector for Grant Thornton –
Modelling gas and power markets in Greece, with the view to assess LNG impact
________________________________________________________________________________________________________________________________
• 15 minutes – Speaker 3: IOANNIS CHRISTODOULOU, Senior Energy Market Analyst for Energy Exemplar –
Gas storage optimisation and uncertainty
________________________________________________________________________________________________________________________________
• 15 minutes – Speaker 4: Dr. ANDRZEJ SIKORA, Chairman of the Board for Energy Studies, Institytut Studiow Energetycznych –
LNG perspective for Central and Eastern Europe
________________________________________________________________________________________________________________________________
• 5 minutes – Round Table Discussion – on 2 chosen questions
• 10 Minutes – Questions and Answer session
_________________________________
Power and GasCo-optimisation
Tracey Granger
Energy Exemplar is 100% focused on simulation software
• Trusted as the de facto standard of TSOs around the world
• Tested and proven by the market’s largest network of 1,700+ users
• Chosen by more than 300 customers for multi-million-dollar decisions since 1999
• Shared expertise and best practices across organisations in 60+ countries
• Skilled technical and customer support teams across eight offices worldwide
• Investing in the largest R&D team across the industry
PLEXOS has Multiple Use Cases
Energy Exemplar has the largest installation base globally of any simulation and optimization software
•ENTSO-E, National Grid, TERNA, REE, ENGIE, Shell, IEA, IRENA, EC-JRC….plus 8 out of TOP 10 utilities
Europe
•Saudi Aramco, TRANSCO, DEWA, ADWEC…Middle East
MISO, PJM, NREL, XCEL…North
America
•China Light and Power (CLP)
•AEMO, METI, MHI & all main AUST UtilitiesAsia Pacific
7
Electricity & Gas markets are converging as more linkages emerge
Primary fuelsConversion/processing
technologiesEnd use
Coal
Natural Gas, LPG, Coal Seam Gas
Oil
Renewables
Power Generation
Gas Processing Facilities
Refineries
Hydrogen Production
Industrial
Residential
Commercial
Transport
Electricity Modelling
Gas Modelling
Other: Biomass, Nuclear, etc.
Momentum for change: unintended consequences of stringent climate targets
ENTSOs scenarios show power & gas can no longer be considered separately
• “ENTSOs scenarios are dependent on further development of sector coupling, without these interlinkages a high or even full decarbonisation in the energy sector will not be reached.”
• “P2G becomes an enabler for the integration of variable RES and an option to decarbonise the gas supply.”
• Central case (“National Trends”) predicts 30GW of P2G within 20 yearso More than the peak demand of Poland
o The Distributed Energy case has over 500GW of P2G generating over 800 TWh of gas by 2040 – that is 20% of our current European gas import volume
This model may work for now…
Electricity
Demand
Conventional
Plant
Fuel (Gas)
Heat
Gas
plant
Battery
Renewable
Generation
Electricity
Node
But this is the future…?
Symbol Class Description
Gas Field Field from which gas is extracted
Gas Storage Storage where gas can be injected and extracted
Gas Pipeline Pipeline for transporting gas
Gas Node Connection point to gas network
Gas Demand Demand for gas covering one or more nodes
Gas Zone A collection of Gas Nodes
Symbol Class Description
Gas Field Field from which gas is extracted
Gas Storage Storage where gas can be injected and extracted
Gas Pipeline Pipeline for transporting gas
Gas Node Connection point to gas network
Gas Demand Demand for gas covering one or more nodes
Gas Zone A collection of Gas Nodes
Gas
field
Symbol Class Description
Gas Field Field from which gas is extracted
Gas Storage Storage where gas can be injected and extracted
Gas Pipeline Pipeline for transporting gas
Gas Node Connection point to gas network
Gas Demand Demand for gas covering one or more nodes
Gas Zone A collection of Gas Nodes
Industrial
Symbol Class Description
Gas Field Field from which gas is extracted
Gas Storage Storage where gas can be injected and extracted
Gas Pipeline Pipeline for transporting gas
Gas Node Connection point to gas network
Gas Demand Demand for gas covering one or more nodes
Gas Zone A collection of Gas Nodes
Domestic
LNG
Terminal
Electricity
Demand
Symbol Class Description
Gas Field Field from which gas is extracted
Gas Storage Storage where gas can be injected and extracted
Gas Pipeline Pipeline for transporting gas
Gas Node Connection point to gas network
Gas Demand Demand for gas covering one or more nodes
Gas Zone A collection of Gas Nodes
Symbol Class Description
Gas Field Field from which gas is extracted
Gas Storage Storage where gas can be injected and extracted
Gas Pipeline Pipeline for transporting gas
Gas Node Connection point to gas network
Gas Demand Demand for gas covering one or more nodes
Gas Zone A collection of Gas Nodes
Symbol Class Description
Gas Field Field from which gas is extracted
Gas Storage Storage where gas can be injected and extracted
Gas Pipeline Pipeline for transporting gas
Gas Node Connection point to gas network
Gas Demand Demand for gas covering one or more nodes
Gas Zone A collection of Gas Nodes
Symbol Class Description
Gas Field Field from which gas is extracted
Gas Storage Storage where gas can be injected and extracted
Gas Pipeline Pipeline for transporting gas
Gas Node Connection point to gas network
Gas Demand Demand for gas covering one or more nodes
Gas Zone A collection of Gas Nodes
Conventional
Plant
Fuel (Gas)
Gas Node
gDemand
Gas Node
Heat
Gas
plant
Power to X
Plant
H2
Gas storage
Battery
Renewable
Generation
Electricity
Node
12
Power to Gas (P2G) adds essential flexibility to the electricity market…
• The electricity system is a fast, real time system,
resulting in limited long-
term flexibility; whereas the
gas system is flexible and
longer term and can
provide its flexibility to the
electricity system.
P2G generation
High elec. prices
Low elec. prices
• Surplus renewable electricity generation can’t be effectively stored in the
electricity system, so “free” renewable generation has to be increasingly
curtailed
• P2G converts this surplus electricity to gas and stores it instead (as eg hydrogen)• Essentially operating as a battery, but large scale and using the current gas
infrastructure with limited additional investment or technological risk.
13
…and supports decarbonisation
• One of ENTSOs scenarios forecasts a
significant uptake in P2G generation within
15 years.
• The impact can be seen from the CO2
emissions forecast: from 2034, emissions In
this Sustainable scenario are tracking
significantly below those of the basecase.
Change on the emissions pattern 2034 High P2G
utilisation
14
P2G impacts electricity prices…
• Increased electricity load from P2G, EV and electric heating increase power
prices for the next decade2030s: Higher P2G utilisation
Higher integration of
Renewables and higher
curtailed electricity
“Free” curtailed
electricity from RES is
used for electrolysis at
the P2G plants,
depressing prices
Higher P2G utilisation
increases electricity prices
Reference Case
Additional Renewable
Growth Scenario
• In the 2030s, surplus
renewable generation can
be utilised for increased
P2G, depressing electricity
prices as renewables are
increasingly on the margin
…and enables electricity markets to benefit from gas infrastructure
The gas infrastructure
can transport large volumes over long distances at a fraction of the costs when compared to the electricity grid
Comparison between the BBL natural gas interconnector and the BritNed high-voltage direct-current submarine power cable. Both projects required roughly the same investment for their construction, and both connect the Netherlands and the United Kingdom. However, BritNed only possesses a capacity of 1 GW, whereas the BBL pipeline has a total capacity of more than 20 GW, highlighting the comparative advantage of the gas infrastructure
Hydrogen Europe Vision on the Role of Hydrogen and Gas Infrastructure on the Road Toward a Climate Neutral Economy
Much more gas storage than electricity storage is available now
Gas storage volumes is more than 350 times larger than electricity storage volumes in GGI countries
The above Figure underlines the storage potential of, by way of example, Belgium, Denmark, France, Germany, the Netherlands, Sweden, Switzerland and the Czech Republic. Their gas storage volume amounts to 1,200 TWh of natural gas enabling it to cover today’s average EU gas demand for more than three months. Whereas total electricity storages of 1.5 TWh suffices solely to meet the average electricity demand for fewer than ten hours.
• A high-renewable energy source-based electricity system will therefore need to depend on the gas system to provide energy storage.
• The existing gas infrastructure can provide large seasonal storage capacities
Hydrogen Europe Vision on the Role of Hydrogen and Gas Infrastructure on the Road Toward a Climate Neutral Economy
An arbitrage opportunity too big to ignore?
Methanated
gas price
Electricity Price cap
Hydrogen
conversion cost
Electricity Price floor
Arbitrage
opportunity
Electricity priceP2G generation
Questions?
Dr. Michael Thomadakis
Partner, Energy Sector, Grant Thornton
Member of the Board of Appeals, ACER
Webinar: Modeling Gas Challenges in Competitive
Market, 30 June, 2020
Modelling gas and power markets in Greece, with the view to assess LNG impact
20Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
Entering a complex market model Going from “national” to “regional”
• Moving from “national” to “regional”: wholesale markets in
all EU-MS and 10 CCR regions in place
• From 2022 onward market coupling will prevail:
• “National” dispatch, but with an eye in the “region”
• Interconnection capacity becomes “internal capacity” at real
time
• Reserves treated regionally, also at real-time
• Cross-border trade will intensify
• More interconnection capacity will become available as a
result of Regulation (EU) 2019/943 and PCI projects.
• Need to optimise interconnection capacities
• Governance and rule-setting becomes regional (at least):
TSOs and NRAs need to design and decide “regionally”
• Every “national” entity and market participant needs to
think and act “regionally”
21Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
Sector coupling becomes increasingly important
Source: EC Quarterly Report Q4 2019
• In the short term, low gas prices, high CO2 prices and new RES capacity
displace solid plant production
• In the long run, gas is a bridge fuel to support decarbonization
• Gas markets and infrastructure may offer proxy-hedging opportunities
• Power and Gas markets need to be considered together
Gas
22Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
A new reality emerges in Greece and the neighboring countries
• 4,4 GW of lignite will be
abandoned by 2028
• Target model starts in September
2020 (gradually to June 2021)
• Major gas infrastructure also
operational by the end of 2020
• New FSRUs licensed (ca 5 bcma)
• New CCGTs (2,6 GW) also
licensed
• Renewables penetrating fast
• HEnEx operational: both power
and gas (VTP) by 2021
• A new reality emerges for market
participants
• New challenges and opportunities
23Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
Italy
Albania
North
Macedonia
Turkey
Bulgaria
Greece
PP-Natural Gas PP-Coal PP-Hydro PP-PV PP-Wind
Market simulation is a necessity (gas & power Plexos)
24Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
The price of gas (including LNG) shall shape the electricity market during at least the next decade
20
25
30
35Greek gas price in 2019
Actual gas price
Simulated gas price
Greece
Power node
Gas node
TurkeyBulgaria
LNG
2021 2022 2023 2024 2025 2026 2027 2028 2029 2030
Evolution of generation mix
Exports
Imports
Natural gas
Lignite
Wind
PV
Italy
25Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
Back-casting of SMP in Greece for 2018-2019
0
20
40
60
80
100
Price [
EU
R/M
Wh]
Weekly system marginal price
Simulated price Actual price
0
20
40
60
80
100
Price [
EU
R/M
Wh]
Daily system marginal price
Simulated price Actual price
2018 2019
r2 0.931270239 0.823349034
rmse 3.43 3.20
26Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
Greek day-ahead prices become competitive to IT and BG prices post 2025
Jan
May
Sep
Jan
May
Sep
Jan
May
Sep
Jan
May
Sep
Jan
May
Sep
Jan
May
Sep
Jan
May
Sep
Jan
May
Sep
Jan
May
Sep
Jan
May
Sep
2021 2022 2023 2024 2025 2026 2027 2028 2029 2030
Mo
nth
ly A
vera
ged
DA
Pri
ce [
EU
R/M
Wh
]
Greece Bulgaria
Decommissioning of
1 GW lignite plants
New CCGT [0,3 GW]
Decommissioning of
1.1 GW lignite plants
Decommissioning of 1.4
GW lignite plants
New CCGT [0,8 GW]
New Hydro [0,16 GW]
New Lignite [0,66 GW]
Νew CCGT [0,82 GW]
Decommissioning of 0,9
GW lignite plants
New Hydros [0,7 GW]
Decommissioning of last
lignite plant 0,66 GW
Νew gas [0, 66GW]
+80%
wind
+150%
PV
27Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
Market reversal due to climate policies and X-border capacity increase
-1000-750-500-250
0250500750
1000
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
2021 2022 2023 2024 2025 2026 2027 2028 2029 2030
Net
po
wer
flo
w [
GW
h]
without market coupling with market coupling new interconnection
-300
-200
-100
0
100
200
300
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
Jan
Ap
r
Jul
Oct
2021 2022 2023 2024 2025 2026 2027 2028 2029 2030
Net
po
wer
flo
w [
GW
h]
28Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
The “Clean Spark Spread” curve shows the development of the contribution margins for a CCGT in the Greek electricity market
Cle
an
sp
ark
sp
rea
d [E
UR
/MW
h]
Our estimate on the evolution of clean spark spread in Greece
The vertical red lines implies the variance of the clean spark spread as a function of CO2 prices, gas prices, and total load on the Grid
29Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
Changes are expected to appear in day-ahead and RES remuneration prices under Target model and towards 2030
Power and RES remuneration prices
DAM price
ETA-Base case
ETA-Stress test
30Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
ENTSOG Cost-Benefit Analysis of gas infrastructure projects
Competition Market Integration Security of Supply Sustainability
ENTSO-G CBA Monetised Indicators
Supply Cost Saving (SCS)
Fuel Cost Saving (FCS)
Monetisation of the avoided demand curtailment (CD)
CO2 savings
Simulation flow- North exit [TJ] Actual flow- North exit [TJ]
31Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
CVaR(95%) CVaR(99%) CVaR(99.9%)
Supply
cost
Conditional Value-at-Risk
Under Target model formulating and continuously monitoring hedging strategies and risk exposure is becoming a necessity
Lo
ad
[M
Wh
]
VaR(95%) VaR(99%) VaR(99.9%)
Supply
cost
Value-at-Risk
0
0.2
0.4
0.6
Fre
quency
Supply cost
Hedged Unhedged
32Energy markets modeling and risk management© 2020 Grant Thornton Greece. All rights reserved.
Concluding remarks
• Electricity and gas markets (and systems) become increasingly interrelated
• Market rules are complex and prices are affected by decisions (and parameters) at
the level of minutes (if not seconds…) with significant cross border implications
• Significant infrastructure development in SEE affects and is affected by the target
model(s)
• Decision making needs sophisticated support
• Market simulation becomes a necessity
• We are progressing with the modelling of the gas and power markets of Greece
and its neighboring countries, but this is a significant investment
• PLEXOS seems to be the right tool for this: it evolves with the market and supports
you as needed!
• Deep knowledge of the markets is of paramount importance
Modelling gas and power markets in Greece, with the view to assess LNG impact
Thank you for your attention!
Uncertainty and gas storage optimization
Agenda
• Co-optimization and uncertainty
• How to deal with uncertainty
• Introduction to the study
• Gas storage optimization and uncertainty
Co-optimization vs Single-system approach
The main difference between the two approaches is based on the way that the problem is formulated and solved
• Single system approach. The software has two separate models/modules and each of them has different system technoeconomic characteristics.
• Co-Optimisation. The coupling equations describing the interconnection between the two networks are solved simultaneously for each simulation time step and account for both system technoeconomic characteristics
Uncertainties in a co-optimised environment
GT1
GT2
NG
Electricity
Electricity
NG WHRB_1
NG
NG ST
WHRB_2
NG
Boiler_1
Heat
Heat
Electricity
Heat
Gas Pipeline
Gas Field 1
Gas Field 2
Gas Node
Gas Node
Gas Flow
Gas Flow
Produced Gas
Produced Gas
HP Steam HeaderHeat Node
Heat Recover Node 2
Heat Recover Node 1
Gas Fuel
Gas Demand
Gas Module
Heat Module
Electricity Module
Heat
Hydro Gen
Electricity
Electricity
Coping with Uncertainty
PLEXOS offers three distinct approaches to coping with uncertainty:
1. Scenario analysis
2. Monte Carlo simulation
3. Stochastic optimisation
In PLEXOS any parameter can easily have uncertainty applied to it.
Common parameters to undertake analysis of include:
• Load growth and load shapes
• Fuel and emission prices
• Renewable uptake and energy production
• Technology cost trends
Monte Carlo Simulation and Stochastic Optimisation
Sample 1
Monte Carlo
simulation 2020 2022
Jan DecFeb
Windy FebSunny April Windy Cost optimal gas
storage trajectory
policy
Perfect foresight for the two years uncertainties
Uncertainties can be
• Load growth and load shapes
• Fuel and emission prices
• Gas supply,
• Random events,
• Variable production cost etc.,
Monte Carlo Simulation and Stochastic Optimisation
Sample 1
Sample 2
Sample N
.
.
.
.
Monte Carlo
simulation 2020 2040
With a perfect foresight we have always the most cost optimal solution but what happens if the we choose (e.g., policy for sample 1) is used on scenario 2
Monte Carlo Simulation and Stochastic Optimisation
Sample 1 Policy
Sample2
Uncertainties
Monte Carlo
simulation 2020 2040
Policy 1 is not suitable for sample 2
Gas trajectories follow wrong pattern
e.g., injection on periods that is not needed and withdrawal in periods will low demand
not needed
needed
Monte Carlo Simulation and Stochastic Optimisation
Sample 1
Sample 2
Sample N
.
.
.
.
Monte Carlo
simulation
Stochastic
Optimisation
2020
Stochastic
What happens if policy for sample 1 is followed but uncertainties from sample 2 finally happen !!?
2022
Jan DecFeb
PLEXOS Modelling Framework
System Planning and Market Analysis
Infrastructure Planning
Mid Term OperationShort Term Operation
One Single Model
Capital Investment Decisions• Cost Benefit Analysis• Build Decisions –
Generator/Pipeline/Storage/Transmission
• Security & Reliability
Longer Term Decisions• Gas Storage Levels• Fuel Contract
Optimization• Maintenance Scheduling • Climatic Stress Analysis
Operating Characteristics• Ramping Constraints• Start up Constraints • Operational Constraints
5 min1 hour1 month1 year20+ years 1 sec2+ years
PLEXOS case study Gas Storage optimisation
Stochastic Drivers/ Uncertainty
CCGT1
Electricity
NG
NG
Heat
Gas Pipeline
Gas Field 1
Gas Field 2
Gas Node
Gas Node
Gas Flow
Gas Flow
Produced Gas
Produced Gas
Gas Fuel
Gas Demandfor power Generation
Gas Module
Electricity Module
Electricity
Electricity CCGT2
Wind gen1
Wind gen2
Industrial gas demand
PLEXOS case study Gas Storage optimisation
❖ Wind Rating: One of the critical challenges of wind power integration is the variable and uncertain nature of the resource.
❖ Fuel Price Variation: fuel prices can change the dynamic of the supply stack and can directly affect the demand for gas for power generation
❖ Weather temperature: Variation of the weather temperature affect the demand for gas for heat generation
❖ Industrial Gas Demand: level of uncertainty related to gas demand for industrial use.
Gas storage Withdrawals
Monte Carlo samples
Stochastic
Optimisation Policy
Cost to serve demand
Monte Carlo simulation with
stochastic values from sample
1 but policy from sample 2
Monte Carlo simulation
Sample 1
Gas Demand Shortage
Monte Carlo simulation with
stochastic values from sample
1 but policy from sample 2
Monte Carlo simulation
Sample 1
Gas Demand Shortage
Monte Carlo simulation with
stochastic values from sample
1 but policy from sample 2
Monte Carlo simulation
Sample 1
Stochastic optimisation
Scenarios trees are used to define non – anticipativity constraints for scenario –wise decomposition formulation
Multistage Stochastic Optimization – Non Anticipativity Constraints
0
1
2
3
Stages
𝑥1 𝑥2 𝑥3 𝑥4 𝑥5 𝑥6 𝑥7 𝑥8 𝑥9 𝑥10
𝑥12 = 𝑥2
2 𝑥42 = 𝑥5
2 = 𝑥62
𝑥11 = 𝑥2
1 = 𝑥31 = 𝑥4
1 = 𝑥51 = 𝑥6
1 𝑥71 = 𝑥8
1 = 𝑥91 = 𝑥10
1
𝑥10 = 𝑥2
0 = 𝑥30 = 𝑥4
0 = 𝑥50 = 𝑥6
0 = 𝑥70 = 𝑥8
0 = 𝑥90 = 𝑥10
0
𝑥82 = 𝑥9
2 = 𝑥102𝑥7
2𝑥32
Each decision variable
needs to have non -
anticipativity constraints.
ie:
• Storage Trajectory
• Generation
• Storage End
Volumes
• Transmission flows
Scenario tree dimensionalityWhen using several stages and uncertainties, a huge number of different scenarios is created.
A “stage” is generally a week or month and the horizon is multi-annual, long enough to model very long-term storage
.
.
.
Stage 1 Stage 2 Stage 3 Stage TRoot
In general we will have that number of
scenarios are equal to:
Branches_perStage NStages
Example 21 stages and 3 branches per node
321 = 1.04604 × 1010Scenarios!!
The ‘problem’ with multi-stage SO is the simulation size/memory/runtime increases exponentially as stages are added
PLEXOS is using statistical algorithms to reduce the samples and optimise the execution time
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 54
LNG perspective for Central and Eastern Europe
Andrzej P. Sikora PhD. Eng.,
Energy Studies Institute Ltd.
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 55
Disclaimer
The information on which this presentation is based
derives from our own experience, knowledge, data and research.
The opinions expressed and interpretations offered
are those of Energy Studies Institute
in Warsaw and have been reached
following careful consideration.
However, the Oil&Gas business is characterized
by much uncertainty and all of our comments
and conclusions should be taken in that light.
Accordingly, we do not accept any liability
for any reliance which our clients may place on them.
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 56
„Your task is not to foresee
the future, but to enable it.”
Antoine de Saint-Exupéry
„Citadelle or The Wisdom of the Sands (1948)”
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 57
European natural gas flows
Source: Timera Energy
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 58
LNG perspective for CEE – KRK 2021 & GDAŃSK2025
Simplified Western Europe Gas Flow Patterns and Hubs. Source: RBN Energy
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 59
Oversupply in EuropeA rise in global liquefied natural gas (LNG)
supply due to sluggish demand in Asia, two
warm winters and reduced industrial
demand due to the coronavirus pandemic,
have resulted in unusually high European
Gas stocks.
U.S. vs. European Benchmark Natural Gas Prices. Source: Bloomberg
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 60
US LNG export to Europe
Bcm natural gas equivalent
https://www.eia.gov/naturalgas/weekly/?scr=email
https://www.spglobal.com/platts/en/market-insights/latest-news/natural-gas/052820-us-lng-exports-to-europe-already-crumbling-
ahead-of-cancellations
LNG deliveries are expected to be lower. Few dozens of cargoes for
loading in the United States have been cancelled for June and July.
“We now expect around 125 U.S. cargoes to be shut-in this
summer, potentially slashing LNG deliveries to Europe by up to 12
bcm compared to what was expected at the start of the summer,”
consultancy Energy Aspects said.
Qatari deliveries are also expected to be reduced as higher prices
in Asia mean it’s more profitable to send cargoes to India and
northeast Asia, one LNG trader said.
Henry Hub daily natural gas spot price reaches historic low
The average spot price of natural gas at the Henry Hub reached
$1.38 per million British thermal units (MMBtu) on June 16, 2020,
the lowest daily Henry Hub price without adjusting for inflation and
in nominal dollars since December 1998, according to data from
Natural Gas Intelligence. After starting 2020 relatively low, the price
at Henry Hub so far this summer has continued to trend low
because of high natural gas storage levels and declines in natural
gas demand, specifically in exports of liquefied natural gas (LNG)
feedgas and in the industrial sector.
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 61https://www.msn.com/en-us/finance/markets/europe-bailed-out-by-cheap-lng/ar-AABhTR9
Natural gas is no stranger to negative prices in
Europe. U.K.‘s NBP plunged below zero in 2006
after a pipeline opened for commercial imports
from Norway. In the U.S., associated gas, a
byproduct of shale drilling, has periodically gone
negative due mainly to increased production
coming up against limited transport capacity at
places such as the Waha Hub in West Texas.
The ‘Clean Energy for All Europeans’ package
is made up of nine legislative proposals and
seven non-legislative documents, covering
energy efficiency, renewable energy, electricity
market redesign, governance rules for the
Energy Union, energy security and eco-
design.
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 62
Natural gas market in the CEE & Baltic Region
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 63
Terminals in CEE
WARSAW, May 29/June 24 (Reuters) - Poland’s dominant gas firm PGNiG said it has increased
its regasifiaction capacities at the Swinoujscie liquefied natural gas (LNG) terminal to 6.2 bcm from
5 bcm currently in 2022 when its long-term supply deal with Russian Gazprom expires. Poland has
signed contracts worth 1.9 billion zlotys ($483 million) to expand its liquefied natural gas (LNG)
terminal in Swinoujscie on the Baltic Sea to 8.3 billion cubic metres (bcm) by 2023 from 5 bcm now
in response to increasing domestic demand.
“The Swinoujscie terminal is one the best used units of this kind in Europe,”
In 2019 PGNiG bought 3.43 bcm of LNG, around 25% more than a year earlier. In the first quarter
the group purchased 0.98 bcm of LNG, a 34% increase year on year.
PGNiG said it expects its 100th shipment of LNG in a month.Earlier this month.
OIES Nov 2019 Jim Henderson
Russian LNG:Becoming a Global Force
Potential outlook for Russian LNG
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 64
Conclusions
➢ Oversupply – not only in Europe – Floating storage is being used extensively
➢ EE was determined and usually supplied by Russian (FSU) natural gas based on oil linked long term contracts
➢ Shale gas revolution, oversupply; cheaper spot LNG prepared infrastructure opened the possibilities for CEE EU
countries and Ukraine for LNG and diversification
➢ Poland’s dominant natural gas firm PGNiG decided to increase its regasifiaction capacities at the Świnoujście
liquefied natural gas (LNG) terminal to 6.2 bcm from 5 bcm currently in 2022 when its long-term supply deal with
Russian Gazprom expires and to 8.3 bcm by 2023 in response to increasing demand.
➢ PGNiG expects its 100th shipment of LNG in June. The Świnoujście terminal is one the best used units of this kind
in Europe - In 2019 PGNiG bought 3.43 bcm of LNG, around 25% more than a year earlier. In the first quarter 2020
the group purchased 0.98 bcm of LNG, a 34% increase year on year.
➢ Demand forecasts for CEE shows the increase of consumption by 15% till 92 -95 bcm/yr in 2035 (from 80 bcm /yr
in 2018)
➢ Russian LNG Becoming a Global Force – Novatek is following the global trend and Russia has the potential to stay
4th – 5th market player in LNG
.
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 65
Thank you for your attention ☺
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 66
LNG Germany
In September 2019, German LNG Terminal, the joint venture of Vopak,
Oiltanking and Gasunie completed the EPC pre-qualification process
to construct an onshore LNG import terminal in Brunsbüttel in Northern
Germany, with subsequent EPC contract award planned before the
end of April 2020. The permit request will include two tanks of 240,000
m³ as well as a jetty for vessels and barges of up to 265,000 m³. Some
of the milestone decisions leading up to the FID will be taken in early
2020. Commercial operations will start following a construction phase
that will take up to three years.
The development of the first offshore German LNG regasification
terminal in Wilhelmshaven also progressed during the year. Mitsui
OSK Lines and Uniper signed an MoU to seal a cooperation to design
and operate the FSRU. Alongside regasification and injection into the
transmission grid, the FSRU will offer the possibility of loading LNG
onto bunker barges or tank trucks for road transport. The FSRU has a
planned send-out capacity of 7.3 MTPA and an LNG storage capacity
of around 263,000 m³.
In January 2019, Uniper entered into a HOA with ExxonMobil to book
a share of regasification capacity long-term.
LNG STADE (Macquarie Group Ltd.& China Harbor
Engineering); 2020 all permissions
Planed costs ca.: 500 mln €; uruchomienie 2023;
Capacity i ok. 5-8 mld m³/yr.
UNIPER - FSRU w Wilhelmshaven: ca 7.3 MTPA;
(10 mld m³/yr) German utility Uniper signed a contract
with Japanese group Mitsui OSK Lines to build and
charter a ship to handle deliveries of liquefied natural gas
(LNG) into Germany’s planned terminal at Wilhelmshaven
(LTW), it said on Mai 26th.
Q-Max 260 tys. m³.
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 67
Data sources
https://www.bp.com/en/global/corporate/energy-economics/energy-outlook.html
„LNG perspective for Central and Eastern Europe” June 30th. 2020. 68
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„LNG perspective for Central and Eastern Europe” June 30th. 2020. 69
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