decarbonizing power generation: the hydrogen-fuelled gas

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 2018 M.J.Welch / Siemens AG

© Siemens AG 2018 All rights reserved.AL: N ECCN: N

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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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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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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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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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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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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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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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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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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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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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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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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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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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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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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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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Solar PV generation varies greatly in minutes !

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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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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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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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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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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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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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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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• 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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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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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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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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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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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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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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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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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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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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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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• 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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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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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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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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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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• 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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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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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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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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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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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

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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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The Carbon Emissions

• 100MW Power Plant

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55% Efficiency,100% H2


H2 / natural gas blends or 100% H2 can reduce CO2 emissions

CO2 Emissions Tonnes/Hour

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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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The Economics…. Fuel Costs Only

• 100MW Power Plant• Natural Gas @ £22/MWh• Hydrogen @ £110/MWh

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40% EfficientNG

55% EfficientNG

60% EfficientNG

65% EfficientNG


NG Blend



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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The Economics…. Fuel Costs + CO2 Tax• 100MW Power Plant• Natural Gas @ £22/MWh• Hydrogen @ £110/MWh• CO2 Tax @ £20/tonne

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55% EfficientNG

60% EfficientNG

65% EfficientNG


NG Blend



Low levels of Carbon Tax don’t really help

Fuel Cost + Cost of CO2, £/Hour

4 1/4 x asexpensive!

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55% EfficientNG

60% EfficientNG

65% EfficientNG


NG Blend



Even a relatively high level of Carbon Tax doesn’t close the gap sufficiently


2.6 x asexpensive!

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The Economics…. Fuel Costs Only

• 100MW Power Plant• Natural Gas @ £22/MWh• Hydrogen @ £71/MWh

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NG Blend



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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NG Blend



Calculated current cost of Bio-H2 costs plus high Carbon Tax closes the gap a bit more


1.67 x asexpensive!

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The Economics…. Fuel Costs + CO2 Capture• 100MW Power Plant• Natural Gas @ £22/MWh• Hydrogen @ £71/MWh• CO2 Capture @ £55/tonne

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Carbon Capture plus current projected Bio-H2 costs still aren’t enough…


2.2 x asexpensive!

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Reducing the cost of H2 production can make deep decarbonization of power generation affordable


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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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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A final thought...

“Water will be the coal of the future”The Mysterious Island, published 1874

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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:[email protected]

siemens.com/power-gas

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mailto:[email protected]






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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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

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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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decarbonizing power generation: the hydrogen-fuelled gas

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