Post on 15-Feb-2022
Decarbonizing Power Generation:the Hydrogen-fuelled Gas TurbineMichael WelchIndustry Marketing Manager
siemens.com/power-gas© Siemens AG 2018 All rights reserved.
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November 2018Page 2 M.J.Welch / Siemens AG
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Disclaimer
This document contains statements related to our future business and financial performance and future events or developments involving Siemens that mayconstitute forward-looking statements. These statements may be identified by words such as “expect,” “look forward to,” “anticipate” “intend,” “plan,” “believe,”“seek,” “estimate,” “will,” “project” or words of similar meaning. We may also make forward-looking statements in other reports, in presentations, in materialdelivered to shareholders and in press releases. In addition, our representatives may from time to time make oral forward-looking statements. Such statements arebased on the current expectations and certain assumptions of Siemens’ management, of which many are beyond Siemens’ control. These are subject to a numberof risks, uncertainties and factors, including, but not limited to those described in disclosures, in particular in the chapter Risks in Siemens’ Annual Report. Shouldone or more of these risks or uncertainties materialize, or should underlying expectations not occur or assumptions prove incorrect, actual results, performance orachievements of Siemens may (negatively or positively) vary materially from those described explicitly or implicitly in the relevant forward-looking statement.Siemens neither intends, nor assumes any obligation, to update or revise these forward-looking statements in light of developments which differ from thoseanticipated.
Trademarks mentioned in this document are the property of Siemens AG, its affiliates or their respective owners.
TRENT® and RB211® are registered trade marks of and used under license from Rolls-Royce plc.Trent, RB211, 501 and Avon are trade marks of and used under license of Rolls-Royce plc.
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November 2018Page 3 M.J.Welch / Siemens AG
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Table of Contents
• Reducing Greenhouse Gas Emissions from Power Generation
• The Challenge of Integrating Intermittent Renewable PowerGeneration
• Sources of Hydrogen
• Hydrogen as a Gas Turbine Fuel
• The potential impact on Power Generation of Hydrogen as a Fuel
• Conclusions
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Reducing Greenhouse GasEmissions from Power Generation
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November 2018Page 5 M.J.Welch / Siemens AG
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Reducing Greenhouse Gas Emissions from Power Generation
Fossil fuel combustion produces CO2• 1/3 of EU CO2 emissions come from Power Generation
Power and Heat Generation makes a significant contribution to global GHG emissions
CO2 Emissions by sector
Power & HeatGenerationOther EnergyIndustry UseManufacturingindustryRoad transport
Other transport
Residential sector
Other Buildings
Source IEA, 2015c
CO2 Emissions by fuel (%)
CoalOilGasOther
Coal and Gas dominate Power & Heat, Manufacturing,Oil dominates transport
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November 2018Page 6 M.J.Welch / Siemens AG
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Reducing Greenhouse Gas Emissions from Power Generation
The Energy Trilemma
Access to electricity is key for economic developmentand improved quality of life
• Requirement for affordable electricity• Security of power supplies: 24/7• Minimum environmental impact
• Drives the need for:Low infrastructure investment costsLow cost fuelsLow carbon power generation
Security ofSupply
Security ofSupply
Price ofEnergyPrice ofEnergy
EnvironmentEnvironment
Requires a Global solution to a Global problem
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November 2018Page 7 M.J.Welch / Siemens AG
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Reducing Greenhouse Gas Emissions from Power Generation
In the US ‘belief’ in science is still amatter of politics
In Washington, Trump’s administration isignoring and overruling its own scientists
Meanwhile states, Cities and some businessestake a different view
USALobbying for the science in a worlddominated by cheap shale gas
In Germany politics drive anti-nuclear and pro-renewables action
The Energiewende spent a fortune and hashardly reduced German greenhouse emissions
Further cost to customers must show industrialbenefit
GermanyFocus on Coal to gas switching and lowercarbon technology solutions
The UK focus is on carbon dioxideand winning a global deal
All party support for 2008 Climate Change Act –A slow start but tangible progress
The hard part is yet to come but net zero will bethe next target
UKOpportunity to offer fully decarbonisedsolutions
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November 2018Page 8 M.J.Welch / Siemens AG
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Reducing Greenhouse Gas Emissions from Power Generation
CO2 emissions depend on fuel and efficiency
CO2 Emission Factors (T per MWh) Typical overall energy efficiency range
Fuel Switching: Natural Gas-fuelled Cogeneration offers the lowest CO2 emissions for fossil fuels
0 20 40 60 80 100
Cogeneration
Separate Heat & Power
Combined Cycle
Open Cycle
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November 2018Page 9 M.J.Welch / Siemens AG
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Reducing Greenhouse Gas Emissions from Power Generation
The traditional approach: bigger and more efficient !
1991 50%
SGT5-2000E
CCPP Killingholme2x1 / 2 x 450 MW
1999 56%2011 60%
2008 58.5%
Reference examples | All performance data based on ISO conditions on site
2016 61.5% 2017 >63%
SGT5-4000F (intro)
CCPP Cottam1S / 390 MW
SGT5-4000F (latestupgrade)
CCPP Mainz-Wiesbaden1x1 / 405 MW
SGT5-8000H (intro)
CCPP Irsching 41S / 578 MW
SGT5-8000H
CCPP Lausward Fortuna1S / 603.8 MW
New SiemensHL-ClassPower output SC/CC50 Hz 567 / 841 MW60 Hz 388 / 577 MW
< overview
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November 2018Page 10 M.J.Welch / Siemens AG
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Reducing Greenhouse Gas Emissions from Power Generation
Switch to lower Carbon fuels or use ‘Opportunity’ Fuels
• Switch from coal and fuel oils to natural gas and propane / LPG
• Utilize process off-gas or waste gases• Avoid GHG emissions from flaring (or venting)• Fully or partially displace fossil fuel consumption
• Gasification and Pyrolysis• Reduced carbon content in fuel gas
• Hybrid Solutions• Integrate with batteries/renewables to partially displace fossil fuel
consumption• Potential to use non-carbon containing fuels
GHG reductions possible by evaluating options for both primary and back-up fuels
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November 2018Page 11 M.J.Welch / Siemens AG
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Reducing Greenhouse Gas Emissions from Power Generation
CO2 is not the only GHG: Methane emissions have a global warming impact
• 12.4 years lifetime in atmosphere
• 84 times global warming potentialof CO2 over 20 years
• Methane emitted as unburned fuel• Otto cycle engines: high methane slip,
increasing as load reduces(up to 40g/kWh at 25% load)
• 6.2g/kWh methane slip = GHG of diesel
• Leakage from ‘wellhead to chimney’• Production well• Gathering pipelines and processing plant• Transmission pipeline network• Distribution pipeline network• Combustion
GHG Global Warming Potential expressed as CO2 equivalent(Source: IPCC Climate Change 2014 Synthesis Report (AR5))
c. 3% methane losses from ‘wellhead to chimney’ has GHG emissions equivalent to coal
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November 2018Page 12 M.J.Welch / Siemens AG
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Reducing Greenhouse Gas Emissions from Power Generation
Hydrocarbons power our world
But burning them releases carbon dioxide, agreenhouse gasAnd ‘natural gas’ = fossil methane (CH4) agreenhouse gas 85 times* more damaging than CO2
How can we use the hydrogen without the carbon?• *for the first 20 years in the atmosphere, Source: IPCC AR5 table 8A1
The world must be net greenhouse gas neutral by 2050IPCC SR15, October 2018
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November 2018Page 13 M.J.Welch / Siemens AG
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Reducing Greenhouse Gas Emissions from Power Generation
To achieve the deepDecarbonization targets set for2050, burning natural gas (aka fossilmethane) must stop
Either - Change what goes in
Use alternative fuels with no greenhouse gasemissions
Production of these alternatives involveseither carbon capture and use or storage(CCUS) or renewable power and electrolysis
As an interim lower lifecycle emission fuels(bio-ethanol, BECCS, anaerobic digestion)can be a helpful pathway but UK governmentkeen to avoid lock in.
Or - Catch what comes out
Capturing the CO2 post combustionUp to 90% capture still makes gas generationhigher carbon than wind, nuclear or evensolar
CCUS is also required for other sectors of theeconomy
Natural gas =methane, CH4
HydrogenH2
AmmoniaNH3
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The Challenge of Integrating IntermittentRenewable Power Generation
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November 2018Page 15 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
Renewables will play a major role in Decarbonization of Energy and Electricity Generation
But what happens when the wind doesn’t blow and the sun isn’t shining?
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November 2018Page 16 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
In a high RES scenario, how can we….
• Provide the necessary electricity tobalance supply and demand?• Short and longer timescales• Respond to rapid RES power fluctuations
• Store ‘surplus’ renewable energy?
• Maintain a low Carbon footprint?
• Minimize pollutant emissions into andother impacts on the Environment?
• Air, Water, Wastes, Noise
Siemens SGT-750 Gas Turbine
Do conventional power generation technologies have a role to play in a zero carbon future?
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November 2018Page 17 M.J.Welch / Siemens AG
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Introduction
Impact of intermittent renewable power generation
• Rapid changes in fossil fuel power generation outputcaused by non-dispatchable intermittent renewables
• Power plant designed for base load operating asmid-merit or peaking plant
• Part-load operation of centralised fossil plant ormaintained as spinning reserve
• Minimum emissions compliance load• ‘Clean’ natural gas fossil fuel generation under cost
pressures• Security of supply risks, potential for increased CO2
and pollutant emissions• Water constraints• Solar-dominated: 1 cycle, wind-dominated 2 cycles
The current installed generating capacity was not designed for this mode of operation
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November 2018Page 18 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
0
5000
10000
15000
20000
25000
30000
35000England & Wales Power Demand: 12 June 2018 to 19 June 2018
Source: National Grid website30 minute recording period
MWh
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November 2018Page 19 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
0
500
1000
1500
2000
2500
3000
3500
4000UK Wind Generation: 12 June 2018 to 19 June 2018
Source: National Grid website
MWh
Wind generation can vary greatly over a day or week
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November 2018Page 20 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
Solar PV generation varies greatly in minutes !
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November 2018Page 21 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
12 June 2018 to 19 June 2018
Oversupply:Storage
Required
Undersupply:Back-up
GenerationRequired
Undersupply can last days: short-term storage (hours) is not sufficient
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November 2018Page 22 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
0
5000
10000
15000
20000
25000
30000
35000
40000
45000
50000England & Wales Power Demand: Summer/Winter Variation
Source: National Grid website
MWh
01 – 08 January 2018
12 – 19 June 2018
Seasonal load demand variations: RES capacity sized to meet winter demandcould exceed summer demands – longer term (seasonal) storage required
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November 2018Page 23 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
The current practice for Grid Support
• Installations based on multiple ReciprocatingEngines (RICE)• Fast start• Competitive CAPEX• Long-term ‘energy storage’
• Burn fossil fuels• CO2 emissions• NOx, CO, UHC, PM emissions, Methane slip
• Fuel leakage potential• Diesel spillage
• Lubricating oil consumption• Waste generation and SOx emissions
Is using fossil fuels to compensate for non-availability of RES a long term solution ?
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November 2018Page 24 M.J.Welch / Siemens AG
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The Challenges caused by Intermittent Renewables
The Environmental Impact of using RICE to support Renewable Generation
• Zero emission electricity is replaced by a high emission power generation• CO2, CO2 eq, NOx, CO, PM, SOx
0
1000
2000
3000
4000
5000
6000
CO2 CO2 eq
Natural Gas - 3g/kWhMethane SlipNatural Gas - 6g/kWhMethane SlipDiesel
0
50
100
150
200
250
NO2 CO PM SO2
Natural Gas - pretreatmentDiesel pre-treatment
Natural Gas - posttreatmentDiesel - post treatment
Off the scale – 2000mg/Nm3mg/Nm3kg/h
Nominal 10MW RICENet efficiency 46% natural gas, 44% low sulphur diesel (LHV basis)Assumes CH4 has 28 x GWP of CO2
Source: Siemens Source: Delimara PP Phase 3, Malta,Environmental Impact Assessment
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November 2018Page 25 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
A variety of potential technology options
• Some suited for short-term storage, some tolonger term storage• Degradation of storage capacity with time and
cycling• e.g. Batteries
• Storage losses with time• LAES, ETES
• Some may have geographical restrictions• e.g. Pumped Hydro, CAES
• Battery Energy Storage offers cost-effectiveshort-term storage solution
• Hydrogen offers a longer term and seasonalstorage option
1 such as Ammonia, Methanol or others;2 Compressed Air Energy Storage;
3 Li-Ion, NaS, Lead Acid, etc.
Duration
Minutes
Seconds
Hours
Weeks
1 kWPower
100 kW 1 MW 10 MW 100 MW 1,000 MW
Hydrogen & derived chemicals1
Flywheel storage(< 1MW Flywheel, up to 100 MW Turbines)
Supercapacitor
Flow-Batteries
PumpedHydroCAES2
Batteries3
Days
Technology
MechanicalElectrical
Electrochemical
ChemicalThermal
Without Energy Storage, a Renewable Energy future is unlikely to happen
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November 2018Page 26 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
Hydrogen• Short- term, long-term and seasonal storage potential
• Convert ‘constrained’ electricity to H2
• Zero CO2 emissions when combusted• Multiple potential uses for additional decarbonisation
possibilities: sector coupling• Transport, chemicals
• Relatively expensive to produce today• Energy carrier: Needs additional equipment to convert back
to power• May give rise to combustion emissions (NOx)
• Electrolysis: requires water• 50MW CCGT power plant requires c. 3400kg/h of H2
• 56,500 litres/h of water• 175MW electricity for 1 hour to produce sufficient H2 to run a
50MW combined cycle power plant for 1 hour
Siemens Silyzer 200 ProtonExchange Membrane (PEM) Electrolyzer
A low cost source of hydrogen is key to the hydrogen economy
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November 2018Page 27 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
Industry
Mobility
Energy
Exports for differentapplications
Photovoltaic
Wind power
PEMelectrolysis
Gridstabilization
Volatileelectricitygeneration
Gridintegration Conversion/ storage Applications
H2generation
Hydrogen from Renewables enables large scale, long-term storage and sector coupling
• Chemical energy storage• No degradation over time
• Zero carbon fuel• 100% carbon-free back-up powerpossible for intermittent renewables• 100% carbon-free baseload powergeneration
• Additional decarbonisation possibilities• Local / regional / national gas networks• Transportation sector
Is hydrogen just for back-up power generation, or is it a potential baseload fuel?
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November 2018Page 28 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
• Hydrogen burns cleanly: It offers benefits for• Climate protection• Air quality• Resource efficiency
• The challenge is to overcome incumbent fuels, and find a niche alongsideother low carbon technologies
• We need to be able to make, transport, store hydrogen and convert it to usefulenergy, at a competitive cost
• Carbon pricing alone may need to be very high to deliver a hydrogeneconomy based on today’s technologies
• The challenge is to bring down the cost of H2 to beat the incumbents, not waitfor them to be regulated away.
• And to do this quickly to avoid catastrophic climate disruption
HydrogenH2
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November 2018Page 29 M.J.Welch / Siemens AG
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The Challenge of Integrating Intermittent Renewable PowerGeneration
H2 - Fired Generation• Dispatchable• Reliable• Zero Carbon emissions…but not instantaneous
Renewable Generation• Zero Emissions• Economical…but not dependable
Stored Energy• Instantaneously Dispatchable
or Fast Response• Zero or low Carbon emissions…but not continuous
Moving forward to a Zero Carbon Landscape
No single technology can provide reliable, dispatchable, responsive zero carbon electricity
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Sources of Hydrogen
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November 2018Page 31 M.J.Welch / Siemens AG
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Sources of Hydrogen
Today
• Feedstock for chemical industry – often made on site from methane• Fertilizer – responsible for >1% of global greenhouse gas emissions
And soon / increasingly / potentially
• Transport, especially heavier transport e.g. trains and ships• Energy – replacing natural gas in industry and in public gas supply
• Methane / hydrogen blends in the gas transmission and distribution networks• Power and storage – converting power to X when low carbon power is
available and back again when needed• ‘Baseload’ power generation using 100% hydrogen
HydrogenH2
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November 2018Page 32 M.J.Welch / Siemens AG
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Sources of hydrogen
The most abundant element on earth ...
… does not occur naturally in its elemental form
… must be created from substances that containhydrogen• Energy intensive• 65 million tonnes/year currently produced• 96% today from fossil fuels
• Releases CO2 but no incentive today to capture this
• … IHS Markit report: hydrogen defined dependingon its production as:
• Brown• Blue• Green
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November 2018Page 33 M.J.Welch / Siemens AG
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Sources of hydrogen
Brown hydrogen
• Thermochemical processes
• Steam Methane Reforming (SMR) of natural gas• Cost of H2 approx. € 2/kg• 8 to 10kg CO2 released per 1kg H2 (Shell 2017)
• Separated from industrial process off-gas• Propane Dehydrogenation (PDH)• Ethane Cracking• Oil refining• Coking
Steam Methane Reforming plant (courtesy of Air Liquide)
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November 2018Page 34 M.J.Welch / Siemens AG
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Sources of hydrogen
Blue hydrogen
• Gasification when combined with carbon capture• Coal• Wastes• Biomass
• Gasification produces a ‘syngas’ that is predominantlyH2 + CO• Gas separation
• SMR + CCS ?
Coal Gasifier:Courtesy of Shandong Wanfeng Coal Chemical Equipment Manufacturing Co., Ltd.
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November 2018Page 35 M.J.Welch / Siemens AG
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Sources of hydrogen
Green hydrogen
• Produced by processes and sources that can beconsidered ‘CO2 free’
• Predominantly electrolysis• Alkaline Electrolysis (AE)• Proton Exchange Membrane (PEM)• Anion Exchange Membrane (AEM)• Solid Oxide Electrolysis (SOE)
• Electricity from grid infrastructure usingcurrent EU Energy mix: 220 – 230g CO2 per MJ of H2
• Electricity from Renewables: carbon-free
Siemens ‘Silyzer’ PEM Electrolyzer
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November 2018Page 36 M.J.Welch / Siemens AG
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Sources of hydrogen
Today’s Sources and Use
48
18
30
4
Production (%)
NG SMRCoal GasificationOil-basedElectrolysis
53
20
7
20
Usage (%)
Ammonia
RefineryProcessesMethanol
Other
Sources: International Journal of Hydrogen Energy, Volasund et al Source: The Essential Chemical Industry - online
As presented by Nils Røkke, SINTEF, at IGTC-18 Brussels, October 2018
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November 2018Page 37 M.J.Welch / Siemens AG
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Sources of hydrogen
The Cost Position
Extracted from a presentation by Nils Røkke, SINTEF, at IGTC-18 Brussels, October 2018
0
1
2
3
4
5
6
7
8
9
2020 2030 2050
SMR w/o CCS
SMR w CCS
Electrolysis
Natural Gas(est)
Parameter Unit Actual 2020 2030 2050
Low High Low High Low High
Cost ofElectricity
€/kWh 0.1 0.065 0.1 0.060 0.090 0.050 0.080
OperatingTime
(Electrolysis)
h/y 3500 3500 3750 4500 4000 6000
Gas Price €/kWh 0.034 0.037 0.044 0.041 0.054 0.044 0.068
Carbon Price €/t 15 25 30 80 50 150
Cost of CCS €/t 100 80 60
A challenging cost position in the medium term for electrolysis
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November 2018Page 38 M.J.Welch / Siemens AG
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20112015
20182023+
2030+
Sources of hydrogen
Silyzer 100Lab-scale
Silyzer 300Commercial product
First investigationsin cooperation withchemical industryNext generation
Under development
Silyzer 200Commercial product
A suitable source of H2 is required
Silyzer PEM portfolio roadmap• Increasing scale reduces cost of H2 production
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Hydrogen as a Gas Turbine Fuel
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November 2018Page 40 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
Hydrogen as a Gas Turbine Fuel
The Challenges
• Hydrogen burns fast• H2 easily burns upstream towards fuel injection
• Hydrogen has a wide flammable region• H2 can burn at much wider concentration range than other
fuels: there are less safe regions in the burner where“nothing bad can happen”.
• Hydrogen has a low ignition energy• Only a fraction of the ignition energy is needed to get H2
”going” compared to methane
• But these challenges are well understood• Globally gas turbines have logged over 10 million
operating hours on fuels containing H2
Risk for flashback and flame position shifting is considerable when high hydrogen concentrations
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November 2018Page 41 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
Hydrogen as a Gas Turbine Fuel
• Increased creation of NOx for highamounts of H2
• Risk of flashbacks for high amounts of H2
• Larger fuel flows to be handled in fuelsystem
• Change of explosion risk characteristics
• Possible requirement to use a standardfuel for startup and shutdown (for 100%H2)
• Higher flame temperature/velocity
• Lower Wobbe index (40.6 vs. 48.5MJ/Nm3) > larger volumes for sameenergy content
• Different behaviour of hydrogen/airmixtures compared to gas/air
• Potential for unstable flame at very lowloads
Physics of burning hydrogen in a gas turbine compared to methane
Differences when using hydrogen and natural gas as fuel in gas turbines
Resulting effects to be managed
with H2
w/o H2
flame location closer to the burner
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November 2018Page 42 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
Hydrogen as a Gas Turbine Fuel
Key criteria to consider for any gas fuel
• Wobbe Index• Measure of energy content in fuel• Determines how much fuel is required
• Injector hole sizes• Pipe sizes
• The lower the Wobbe Index, the more fuel required, the largerthe pipes and orifices must be
• Dew Point & Auto-ignition• Ensure fuel stays as a gas and does not ignite outside the
required combustion zone
• Flame Speed• Ensure combustion takes place in correct location
Hydrogen
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November 2018Page 43 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
Hydrogen as a Gas Turbine Fuel
Flame Speed
• Hydrogen has a very high flame speedcompared to natural gas• Ammonia very slow
• Swirler design in lean pre-mix systemsalso impacts flashback potential• As do sharp edges!
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November 2018Page 44 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
Hydrogen as a Gas Turbine Fuel
Emissions
• Hydrogen burns with a hotter flame than natural gas• Increased NOx emissions (Thermal NOx dominates)• Legislation often treats all gases as natural gas
0
200
400
600
800
1000
1200
No Suppression Steam Injection DLE
Natural Gas
100%Hydrogen
? Emission limit non-natural gas fuels
Based on a 5MW Gas Turbine
Achieving low NOx without wet emission control technology is the challenge moving forward
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November 2018Page 45 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
Hydrogen as a Gas Turbine Fuel
Gas turbine modifications
The extent of required modifications depends on:• GT type and age• Hydrogen content in fuel• Emission requirements
Smaller hydrogen concentrations may be handled without anymodifications of standard GT design
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November 2018Page 46 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
Hydrogen as a Gas Turbine Fuel
• 13 machined parts, joined by 18 welds• External pilot gas feed• Weight: 4.5 kg
Traditionally manufactured burner
• 1 single part• Pilot gas feed integrated in structure• Weight: 3.6 kg• Lead time reduction of >75%
AM H2 adapted burner
Additive manufacturing (AM) of burners
Rapid prototyping speeds up development and enables more complex designs to be realised
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November 2018Page 47 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
Hydrogen as a Gas Turbine Fuel
Heavy-dutygas turbines
Industrialgas turbines
Aeroderivativegas turbines
50H
z50
Hz
or60
Hz
60H
z
450 MW
329 MW
187 MW
310 MW
250 MW
117 MW
60 to 71 / 58 to 62 MW
27 to 37 / 28 to 38 MW
4 to 6 MW
48 to 57 MW
40 / 34 to 41 MW
33 / 34 MW
24 / 25 MW
13 to 14 / 13 to 15 MW
8 / 8 to 9 MW
5 / 6 MW
41 to 44 MW
SGT5-9000HLSGT5-8000HSGT5-4000FSGT5-2000ESGT6-9000HLSGT6-8000HSGT6-5000FSGT6-2000E
SGT-A65SGT-800SGT-A45SGT-750SGT-700SGT-A35SGT-600SGT-400SGT-300SGT-100SGT-A05
567 MW
388 MW
Power OutputGas turbine model
2
30
60
55
40
100
50
27
25
10
5
27
10
10
5
30
10
15
15
65
15
65
100
100
WLE burnerDiffusion burner with unabated NOx emissions
DLE burnerH2 capabilities in vol%
Values shown are indicative for new unitapplications and depend on local conditions andrequirements. Some operating restrictions /special hardware and package modifications mayapply. Any project >25% requires dedicatedengineering for package certification.
The goal is to achieve100% H2 capability withminimum emissions
DLE: Dry Low EmissionWLE: Wet Low Emission
Current Siemens Gas Turbine Hydrogen Fuel Capabilities
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The potential impact on PowerGeneration of Hydrogen as a Fuel
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November 2018Page 49 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
Deep Carbonization needs driving interest in H2 for Power Generation
• Different potential routes to the H2 Power Generation Economy developing
• Hydrogen in the Natural Gas Network• H2 / Natural Gas blends• Impacts existing installed equipment• Pipeline network H2 content limitations?
• Hydrogen as a support fuel for intermittent Renewables• Produced locally• Combustion of 100% H2 desirable
• Hydrogen as a baseload fuel for power plants• CO2 associated with H2 production• Combustion of 100% H2 desirable• Cost challenge
Globally different solutions, or a combination of solutions, may be adopted
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November 2018Page 50 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
The UK carbon capture and storage opportunity creates options for hydrogenproduction using SMR with CCS
Europe’s future carbon storage is under the North Sea
UK has related expertise – Offshore oil and gas
Taskforce report launched on 19th July
National Infrastructure Commission (NIC) and governmentfocus for CCS is for H2 production NOT POWER
First hubs may have power ‘anchor tenants’
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November 2018Page 51 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
Increasing H2 content in natural gas will helpdecarbonize energy production
Two possible pathways:
• Gradually increase H2 content in gas pipeline network• Define limits allowed by pipeline operators• Impacts every piece of equipment on gas network• H2 has lower energy content per unit volume than natural
gas, so CO2 impact at low concentrations is limited
• ‘Stand-alone’ power plants on 100% H2 operation• Dedicated source of H2 for the power plant, e.g. SMR• In conjunction with ‘constrained’ renewables, electrolysis and
storage for ‘peakers’ to support wind and solar
65% NG w/oCCS = 304
c. 40% H2 (vol) blend in natural gas creates less CO2 from todays’ CCGT fleet than a future 65% efficient CCGT
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November 2018Page 52 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
Partial displacement of fossil fuel with hydrogenhas a limited impact on CO2 emission reduction
• 100% H2 better from a pure CO2 perspective
• Infrastructure challenges as well as technical /emissions challenges in power generation systems• Transportation
• Ammonia for transportation?• Storage
• Combine with Carbon Capture to maximise impact• Improved economics through CCUS: utilization of CO2
combined with H2• Chemicals etc. 0
50
100
150
200
250
300
350
400
Natural Gas 60% H2 / 40% NG H2/NG Blend with80% Carbon
CaptureComparison of CO2 emissions for a 55% efficient CCGT
32%
83%
CO2 (g/kWh)
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November 2018Page 53 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
The Carbon Emissions
• 100MW Power Plant
0
10
20
30
40
50
60
40% EfficientNG
55% EfficientNG
60% EfficientNG
65% EfficientNG
55% Efficiency,60% H2/40%
NG Blend
55% Efficiency,100% H2
65% Efficiency,100% H2
H2 / natural gas blends or 100% H2 can reduce CO2 emissions
CO2 Emissions Tonnes/Hour
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November 2018Page 54 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
While the Carbon Savings are obvious, can it be economically viable too ?
• Affordability is a key consideration in the Energy Trilemma
• Let’s examine the simple hourly costs of fuel and cost of carbon assuming:• Natural Gas £22/MWh• ‘Green’ or ‘Blue’ Hydrogen
• Electrolysis : £110/MWh• With potential to fall to £30 – 40/MWh in the future due to technology improvements, falling power prices etc.• But how is ‘constrained’ renewable electricity valued? Is it considered free ?
• Bio-Hydrogen: £71/MWh• Potential to fall to £42/MWh based on ‘nth’ plant, scaling etc.
• Bio-hydrogen: produced by gasification of wastes, and assumes a gate fee equivalent to £20.60/MWh• Source: Bio-hydrogen: Production of hydrogen by gasification of waste – A report for Cadent prepared by Advanced
Plasma Power and Progressive Energy, July 2017
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November 2018Page 55 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
The Economics…. Fuel Costs Only
• 100MW Power Plant• Natural Gas @ £22/MWh• Hydrogen @ £110/MWh
02000400060008000
100001200014000160001800020000
40% EfficientNG
55% EfficientNG
60% EfficientNG
65% EfficientNG
55% Efficiency,60% H2/40%
NG Blend
55% Efficiency,100% H2
65% Efficiency,100% H2
At current H2 prices from electrolysis, it’s not economic to use H2 as a power generation fuel
Fuel Cost Only, £/Hour
5 x asexpensive!
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November 2018Page 56 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
The Economics…. Fuel Costs + CO2 Tax• 100MW Power Plant• Natural Gas @ £22/MWh• Hydrogen @ £110/MWh• CO2 Tax @ £20/tonne
02000400060008000
100001200014000160001800020000
40% EfficientNG
55% EfficientNG
60% EfficientNG
65% EfficientNG
55% Efficiency,60% H2/40%
NG Blend
55% Efficiency,100% H2
65% Efficiency,100% H2
Low levels of Carbon Tax don’t really help
Fuel Cost + Cost of CO2, £/Hour
4 1/4 x asexpensive!
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November 2018Page 57 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
The Economics…. Fuel Costs + CO2 Tax• 100MW Power Plant• Natural Gas @ £22/MWh• Hydrogen @ £110/MWh• CO2 Tax @ £100/tonne
02000400060008000
100001200014000160001800020000
40% EfficientNG
55% EfficientNG
60% EfficientNG
65% EfficientNG
55% Efficiency,60% H2/40%
NG Blend
55% Efficiency,100% H2
65% Efficiency,100% H2
Even a relatively high level of Carbon Tax doesn’t close the gap sufficiently
Fuel Cost + Cost of CO2, £/Hour
2.6 x asexpensive!
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November 2018Page 58 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
The Economics…. Fuel Costs Only
• 100MW Power Plant• Natural Gas @ £22/MWh• Hydrogen @ £71/MWh
0
2000
4000
6000
8000
10000
12000
14000
40% EfficientNG
55% EfficientNG
60% EfficientNG
65% EfficientNG
55% Efficiency,60% H2/40%
NG Blend
55% Efficiency,100% H2
65% Efficiency,100% H2
Using a calculated current cost of Bio-H2 reduces the difference, but not enough
Fuel Cost Only, £/Hour
3 x asexpensive!
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November 2018Page 59 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
The Economics…. Fuel Costs + CO2 Tax• 100MW Power Plant• Natural Gas @ £22/MWh• Hydrogen @ £71/MWh• CO2 Tax @ £100/tonne
0
2000
4000
6000
8000
10000
12000
14000
40% EfficientNG
55% EfficientNG
60% EfficientNG
65% EfficientNG
55% Efficiency,60% H2/40%
NG Blend
55% Efficiency,100% H2
65% Efficiency,100% H2
Calculated current cost of Bio-H2 costs plus high Carbon Tax closes the gap a bit more
Fuel Cost + Cost of CO2, £/Hour
1.67 x asexpensive!
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November 2018Page 60 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
The Economics…. Fuel Costs + CO2 Capture• 100MW Power Plant• Natural Gas @ £22/MWh• Hydrogen @ £71/MWh• CO2 Capture @ £55/tonne
0
2000
4000
6000
8000
10000
12000
14000
40% EfficientNG
55% EfficientNG
60% EfficientNG
65% EfficientNG
55% Efficiency,60% H2/40%
NG Blend
55% Efficiency,100% H2
65% Efficiency,100% H2
Carbon Capture plus current projected Bio-H2 costs still aren’t enough…
Fuel Cost + Cost of CO2, £/Hour
2.2 x asexpensive!
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November 2018Page 61 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
The Economics…. Fuel Costs + CO2 Tax• 100MW Power Plant• Natural Gas @ £22/MWh• Hydrogen @ £22/MWh• CO2 Tax @ £20/tonne
0
1000
2000
3000
4000
5000
6000
7000
40% EfficientNG
55% EfficientNG
60% EfficientNG
65% EfficientNG
55% Efficiency,60% H2/40%
NG Blend
55% Efficiency,100% H2
65% Efficiency,100% H2
Reducing the cost of H2 production can make deep decarbonization of power generation affordable
Fuel Cost + Cost of CO2, £/Hour
What if we could make H2for the same price as
natural gas ?
£22/MWh
£26/MWh
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Conclusions
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November 2018Page 63 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
Conclusions
Decarbonization of Power Generation through the use of Hydrogen is challenging today
• H2 can contribute greatly to a reduced Carbon footprint• 100% H2 or as a blend with natural gas
• Technically achievable• Work needs to be done on Dry Low Emissions combustion systems for improved NOx reduction
• Further investigation required on large-scale storage and transportation
• The biggest challenges are economic and policy• Need to reduce the cost to produce hydrogen if it is to be used as a fuel for Power Generation
• Improvement of existing technologies
• Value of constrained Renewable Electricity and Gate Fees for Waste
• Emerging lower cost gasification technologies
• Need policy makers to understand hydrogen is not the same as natural gas !
H2 offers greater decarbonization benefits than higher efficiency CCGT but can the costs become acceptable?
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November 2018Page 64 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
A final thought...
“Water will be the coal of the future”The Mysterious Island, published 1874
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November 2018Page 65 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
Thank you for your attention
Michael WelchIndustry Marketing ManagerSiemens Industrial Turbomachinery Ltd.
Joseph Ruston BuildingPelham StreetLincoln LN5 7FD
United Kingdom
Phone: +44 1522 58 40 00Mobile: +44 7921 24 22 34
E-mail:welch.michael@siemens.com
siemens.com/power-gas
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November 2018Page 66 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
Power
Time
Black start
Frequency responsePFR + SFR
Spinningreserve
Fast ramp-upand ramp-downsupport
Islanding,off-grid
Min. environ-mental load
Hybrid system operation line
Fast start,responsewithin < 1s
Island loadFast start,stress reduced
GT max. load
Primaryfrequencyresponse
Faststart-up
Secondaryfrequencyresponse
Minimumload
Acceleration& stabilizationof load ramps
Islandingoff-grid
Operatingreserve forpeak power
Black start andsupport of gridrestorage
GT operation line (in Hybrid-System operation)
Battery systems improve gas turbine response and operability
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November 2018Page 67 M.J.Welch / Siemens AG
© Siemens AG 2018 All rights reserved.AL: N ECCN: N
The Potential Impact on Power Generation of Hydrogen as a Fuel
Customer benefits:
• Provides 100% of the plant’soutput (80 MW) within milliseconds(<1 sec)
• Provides black start powerto gas turbines
• Battery output tapers offas turbines come online and rampup
• Potential to delay gas turbine start
• Full plant output – immediately andcontinuously
Full plant response within 1 second – from a high efficiency combined cycle plant
-10
0
10
20
30
40
50
60
70
80
90
Gas turbine sync speed
Elec
tric
pow
er (M
W G
ross
)
Time (sec)
Plant output
Battery
Gas turbine power
Steam turbine power
80 MW BESS and 80 MW peaking plant for RES supportImmediate firming capacity with high efficiency combined cycle
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