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Amgad Elgowainy, Ph.D.
Argonne National Laboratory
LWRS-H2 Workshop
University of Toledo, OH
January 14, 2020
Hydrogen for Production of Clean Transportation Fuels & Industrial Processes
Ohio Energy Facts
2
Population ~12M, with GDP ~$680B (state rank #7)
Ohio is the third-largest coal-consuming state after TX and IN
– ~ 90% of the coal is used for power generation
Ohio’s two nuclear power plants, along Lake Erie, supplied about 15% of the state’s net generation in 2018
Rapid increase in Ohio's NG production (Utica shale)
– 28 times higher in 2018 than in 2012
Ohio has the 7th largest crude oil-refining capacity
– Four refineries can process ~ 600,000 bpd
Ohio is the 8th largest ethanol-producing state
– supplying about 550 million gallons per year
Stark Area Regional Transit Authority (SARTA)
– 7 H2 FCEB, with 5 additional planned this year
Ohio net electricity generation by source (EIA 2018)
Goldberg, D., Lu, Z., Oda, T. et al., Science of The Total Environment, 695, 133805, 2019
Ohio Environmental Facts: significant reduction in CO2, SOx, and NOx over time
3
2005
Data are processed by Zifeng Lu @ ANL, based on April to September data
2010-2011 2016-2019
SOx emissions reduction, due to the control of SO2 in coal-fired power plants
2005 2010-2011 2018-2019
NOx emissions reduction control of NOx in power plants and vehicles
H2@Scale enables grid flexibility with more renewables, while creating green opportunities across sectors*
*Illustrative examples, not comprehensive
H2@Scale of Fuel Cell Technology Office of DOE
1600 mi of H2 pipeline; 10 Liquefaction plants in North America
Today, more than 10M metric tons of hydrogen are produced in the U.S. annually
6
Estimated based on facilities’ crude distillation capacity and PADD H2/crude ratios
Facility-level H2 demand for US refineries (2017)
PADD1 PADD2 PADD3 PADD4 PADD5 US
H2 demand (MMT) 0.12 1.2 3.0 0.3 1.4 5.9H2/Crude (ft3/bbl) 100 315 329 430 504 342
Recently, H2 demand for US refineries has increased significantly
H2 demand has been increased due to increased diesel demand and more stringent regulations.
H2/Crude ratio shows regional variation; H2/Crude increases over time.
7
0
1
2
3
4
5
6
7
2009 2010 2011 2012 2013 2014 2015 2016
Hyd
rogen d
em
and f
or
US
refineries
(Mill
ion m
etr
ic
tons
per
year)
PADD1 PADD2 PADD3 PADD4 PADD5
0
100
200
300
400
500
600
2009 2010 2011 2012 2013 2014 2015 2016
H2/C
rude (
cubic
feet per
barr
el)
PADD1 PADD2 PADD3
PADD4 PADD5 US
Estimation of future H2 demand for US refineries
H2/Crude will increase through 2030
Crude capacity would increase 9% from 2015 to 2021 and remain stable for the subsequent years (EIA AEO)
8
PADD1 PADD2 PADD3 PADD4 PADD5 US
H2 demand in 2030 (MMT) 0.2 1.5 3.8 0.4 1.8 7.5
0
100
200
300
400
500
600
700
2010 2020 2030 2040 2050
H2/C
rude (
cubic
feet per
barr
el)
PADD1 PADD2 PADD3 PADD4 PADD5
0.0
1.0
2.0
3.0
4.0
5.0
6.0
7.0
8.0
2010 2015 2020 2025 2030 2035 2040 2045 2050
Hyd
rogen d
em
and f
or
US
refin
eries
(Mill
ion m
etr
ic tons
per
year)
PADD1 PADD2 PADD3 PADD4 PADD5
Generally increasing H2 consumption by refineries– Increasing H2 consumption rate due to heavier and more sour crude
– Increasing D/G ratio
– Increasing crude inputs
POTENTIAL HYDROGEN DEMAND FOR AMMONIA PRODUCTION
9
10
Natural gas
Feedstock
Coal
Petroleum coke
Hydrogen
Others (biomass/biogas/wind)
Assumption: capacity factor 90%
U.S. Ammonia Production 2016
H2 demand: 2.9 MMT NH3 production: 16.2 MMT
US domestic ammonia production and imports varied over time while consumption keeps stable
If the amount of current imported ammonia is produced in the US, domestic production can be increased by 43% without increment in ammonia demand
11
0
2000
4000
6000
8000
10000
12000
14000
16000
18000
20000
1995 2000 2005 2010 2015
Am
monia
import
s a
nd e
xport
s(t
housa
nd m
etr
ic tons
of nitr
ogen)
Year
ProductionImports for consumptionExportsApparent consumption
0
1
2
3
4
5
6
7
8
9
10
0%
5%
10%
15%
20%
25%
30%
35%
40%
45%
50%
1995 2000 2005 2010 2015
US
NG
Indust
rial P
rice
(D
olla
rs p
er
Thousa
nd C
ubic
Feet)
Net im
port
relia
nce
Year
Data: USGS nitrogen (fixed)-ammonia (USGS 2016) Data: USGS 2016; EIA 2017
Green ammonia reduces nitrogen fertilizer CO2 emissions
12
ton
CO
2e
/to
n N
Conventional Green
2.92.4
6.1
3.2
4.6
2.6
3.2
1.0
0.0
3.7
0.9
2.21.9 2.0
0.0
1.0
2.0
3.0
4.0
5.0
6.0
7.0
Ammonia Urea AmmoniumNitrate
AmmoniaSulfate
N Solution MAP DAP0
0.5
1
1.5
2
2.5
3
3.5
Conventional Nuclear-H2,Grid for ASU
Nuclear for H2and ASU
Ammonia Production Pathways
ton
CO
2e
/to
n N
31%
23%
2%2%
32%
4%6%
Urea
Ammonia
MAP
N solution
DAP
Ammonia Nitrate
Ammonia Sulfate
Green ammonia with current N fertilizer shares, reduces CI per ton of N fertilizer from 3.4 ton CO2e to 1.3 ton CO2e, a 61% reduction
- 2019 US grid electricity for ASU and HB- Zero carbon electricity for H2 (nuclear HTGR)
SYNTHETIC FUEL PRODUCTION (H2 +CO2 LIQUID HC)
13
E-fuels
Demand for synthetic fuel production CO2 sources
14
• 100 million MT of concentrated CO2 produced annually (out of total ~5 GT CO2)
44 million MT from ethanol plants
Current market supply capacity of 14 MMT, and demand of 11 MMT
Remainder from hydrogen SMR (refineries) and ammonia plants
Supekar and Skerlos, ES&T (2014)
CO2 + H2 Syngas synfuels
14 MMT of H2 per year may need to be produced close to CO2 and synfuel production locations
15
*Assumption: CO2/H2 mole ratio 1:3
Ethanol plants
Recovered CO2 from
H2 plants
Ammonia plants
Wind electricity potential
Solar electricity potential
Installed nuclear plants
FT fuel WTW GHG emissions FT fuel (the mixture of naphtha, jet fuel, and diesel) production without H2 recycle has the lowest WTW
GHG emissions of -11 g CO2eq /MJ a
Based on carbon neutrality of fermentation CO2 in ethanol plants, GHG emissions reductions of the standalone FT fuel pathway are estimated to be 93% to 113% compared with petroleum pathways
a GHG emissions are evaluated based on GREET 2018
103
94 93 9186
53
8 6
-11
-40
-20
0
20
40
60
80
100
120
FT from naturalgas
Gasoline BOB Diesel Gasoline Jet Dry milling cornethanol
Corn stoverethanol
Standalone FT with H₂ recycle
Standalone FT without H₂
recycle
GH
G e
mis
sions
(g C
O2eq/M
J)
16
METAL REFINING
17
Steel making via DRI and FIT can provide virgin feed to electric arc steel production
18
• 106 million MT of steel consumed in the U.S. in 20171
81 MMT produced (68% electric arc [EA], 32% blast furnace [BF]) 1
Scrap constitute ~15% of BF feed and most of EA feed
Direct Reduction of Iron (DRI)2 or Flash Ironmaking Technology (FIT)3
feedstock enables higher quality steel than scrap metal feedstock
35 MMT imported4
~2 tons of CO2 per ton of steel
1. USGS, 2017. Iron and Steel Statistics. January2. Midrex3. University of Utah4. Global Steel Monitor
• 60-100 kg of hydrogen is estimated to produce 1 MT of hot iron with direct reduction iron (DRI) technology
1 ton of H2 can replace up to 7 tons of coke
Steel making via DRI can induce large hydrogen demand
19
• Use of recycled scrap metal can reduce quality of steel produced by EA over time
• DRI can provide virgin feed to EA furnaces to enable higher steel quality
• 430 kg of coke is required to produce 1 MT of hot iron in BF
DRI using natural gas reduces CO2 emissions by approximately 35% compared to BF
H2 for DRI can virtually eliminate CO2 emissions from the iron-making process
Projected growth from 80 to 120 MMT (50%) by 2040
Ind
ex
(not
qu
antit
y)
0
0.5
1
1.5
2
2.5
Blast Furnace Electric Arc(Grid)
Electric Arc(Nuclear)
DRI(Nuclear H2)
ton CO2e per ton of steel
FUEL CELL VEHICLES
20
MHDVs (Medium- and Heavy-Duty Vehicles)
21
All Power Plants
1.6 million tonne NOx
MHDVs
2.1 million tonne NOx >
Medium- and Heavy-duty Vehicles (MHDVs)
– Have a wide range of vocations, e.g. pick-up & delivery, refuse, tractor-trailer, and sleeper cab
– Contributing significantly to critical air emissions, even though accounting for a small portion of on-road transportation
0.00
0.01
0.02
0.03
0.04
0.05
0.06
0.07
0.08
0.09
0.10
Diesel NG-H2 Nuclear-H2
WTW NOx Emissions (g/ton-mi)
PTW
WTP
Drayage trucks for port application
Compared to diesel counterparts, medium- and heavy-duty (MHD) hydrogen fuel cell vehicles create much less GHG emissions
22
Low-carbon sources are key for sustainable H2 production
Assuming 26 mpg for gasoline ICEV and 55 mpgge for H2 FCEV23
OHIO NUCLEAR PLANT EXAMPLE
24
Potential annual hydrogen demand within 100 miles from the Davis-Besse plant
Davis-BessePlant
New HBI Plant
Potential annual hydrogen demand within 150 miles from the Davis-Besse plant
Points for discussion
27
• Competing/displacing SMR-H2 is challenging due to low cost NG public support will be necessary in the transition
• Established applications (refineries and ammonia) are more likely in the near term compared to new applications (e.g., synfuel production or DRI)
• New applications that may leverage existing infrastructure can readily absorb H2 production at scale e.g., mixing H2 with NG for power generation or industrial applications
• Markets will likely demand steady supply of H2
H2 storage will be necessary
• Nuclear-H2 requires less storage compared to wind-H2
storage cost can be significant
• Proximity of H2 production to demand site is key to its economic potential in the energy system demand at volume or aggregating demand will reduce infrastructure cost per unit energy
delivered
Acknowledgment
The presented analysis have been supported by DOE’s Office of Energy Efficiency and Renewable Energy’s Fuel Cell Technologies Office.
H2@Scale is a multi-National Lab effort. The presented analysis has been supported extensively by NREL and INL
28
29
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For Techno-Economic Analysis (TEA) of hydrogen infrastructure:
https://hdsam.es.anl.gov/
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https://greet.es.anl.gov/