The #H2IQ Hour

The #H2IQ Hour

This presentation is part of the monthly H2IQ hour to highlight research and development activities funded by U.S. Department of Energy’s Hydrogen and Fuel Cell Technologies Office (HFTO) within the Office of Energy Efficiency and Renewable Energy (EERE).

Today’s Topic:

Long Duration Energy Storage Using Hydrogen and Fuel Cells

The #H2IQ HourQ&A

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StoreFAST Model Overview:Long Duration Energy Storage Using Hydrogen and Fuel Cells

NREL: Chad Hunter, Michael Penev, Evan Reznicek, Josh EichmanHFTO: Neha Rustagi, Marc Melaina, Mariya KolevaSPIA: Sam BaldwinMarch 24, 2021H2IQ Hour

This presentation does not contain any proprietary, confidential, or otherwise restricted information.

NREL | 4

Outline

• Methods

• Results

• StoreFAST modelling tool & demo

NREL | 5

High variable renewable energy (VRE) grids will require seasonal energy storage or flexible power generation

• Exceeding ~80% VRE penetration will require seasonal energy storage or flexible low-carbon generation[1][2][3]

– Intermittent operation with low capacity factors

• Limitations of previous studies

– Historic capital costs that ignore potential for future cost reductions

– Limit storage durations to < 12 hours

– Focus on narrow subset of technologies

• Most technologies experience cost reductions over time (learning, scale)

[1] P. Denholm, Renewable Energy 130 (2019) 388-399[2] M.R. Shaner, S.J. Davis, N.S. Lewis, K. Calderia. “Geophysical constraints on the reliability of solar and wind power in the United States.” Energy & Environ. Sci 11 (2018) 914-925[3] B. Pierpont. “Mind the Storage Gap: How Much Flexibility Do We Need for a High-Renewables Grid?” Green Tech Media, June 2017. [4] B. Pierpont, D. Nelson, A. Goggins, D. Posner. “Flexibility: The path to low-carbon, low-cost electricity grids.” Climate Policy Initiative, April 2017. [5] Hydrogen Council, 2020. “Path to hydrogen competitiveness: A cost perspective.”

California

High VRE grid studies must use up-to-date technology costs and

consider all options

Excess VRG

Supply gap

Projected variable renewable generation potential and demand for a 100% VRG California grid throughout one year[4].

Example learning curve

NREL | 6

• Levelized cost of energy (LCOE): Unit price of energy for plant to break even at end of life

• Considers capital costs, finances, return on equity, taxes, O&M costs, and energy input

– Energy storage systems: LCOE includes charging cost (electricity price ÷ RT efficiency)

– Power generation systems: LCOE includes fuel cost (fuel price ÷ discharge efficiency)

• The Storage Financial Analysis Scenario Tool (StoreFAST) provides a general, flexible framework for detailed LCOE calculation and sensitivity analysis across technologies

• Systems designed for 100 MW discharge capacity

• Consider storage durations > 12 hours, up to 7 days

Levelized cost of energy (LCOE) is used as a convenient metric for comparison

LCOE calculation inputs• Capital & O&M costs• Plant size, life, efficiency• Electricity and/or fuel cost• Finance specifications• Annual operation (capacity factor)

Accurately comparing LCOE requires specification of capital and operating costs, system and component performance, and plant financing

LCOE calculation outputs• LCOE comparison• Cost breakdown• Sensitivity analysis• Monte Carlo analysis

https://www.nrel.gov/storage/storefast.html

StoreFAST


NREL | 7

Disaggregation of Energy Storage Systems

Storage• $/kWh-AC• kWh-AC• O&M• Life• 12h-7day

Charging• $/kW• kW• Life• O&M• Efficiency• Energy input

Discharging• $/kW• kW• Life• O&M• Efficiency

Reservoir Rev. pump/turbinePumped Hydro

Diabatic CAES (NG)

Adiabatic CAES

Pumped TES Thermal energy storage

Vanadium flow Electrolytes VRB stack

Hydrogen systems

Hydrogen pipes

Stationary fuel cell

Combustion turbine

HDV PEM fuel cell

Charging, storage, and discharge

systems are evaluated independently

Expander

Geologic cavern storage

Rev. pump/turbine

VRB stack

Compressor

Rectifier

PEMEC

Compressor

12 hours - 7 days

NREL | 8

Parametarization of Flexible Power Generators

• NG-CCs and NG-CTs currently contribute toward grid flexibility

• Many studies consider natural gas with CCS for future flexible power generation systems

• Ethanol offers dispatchable renewable fuel

Discharging• $/kW• kW• Life• O&M• Efficiency

Natural gas with CCS

Ethanol combustion

Natural gas combined cycle

Natural gas combustion turbine

Natural gas

Ethanol

Seasonal storage technologies must be compared to dispatchable low-carbon

power generation systems

100 MWFuel

NREL | 9

NGCC

NGCT

NGCC+90%CCS

EthCC

0%

5%

10%

15%

20%

25%

0.00 0.02 0.04 0.06 0.08 0.10 0.12 0.14 0.16 0.18 0.20

Variable operating expense (2018$/kWh)

Cap

acity

facto

rs (

%)

0%

10%

20%

30%

40%

50%

0% 20% 40% 60% 80% 100%

Charging Capacity Factor

Discharging Capacity Factor

ESS Round Trip Efficiency (AC/AC)

Cap

acity f

acto

rs (

%)

Asset utilization depends on operating costs. PLEXOS modeling used to estimate technology-specific capacity factors

• At least 5 days of storage was desired by the grid in the PLEXOS modeling

• Capacity factors are specific to region (Western U.S.) and scenario (85% VRE)

• PLEXOS NG-CC / NG-CT CFs verified with published CEC data and personal communication with a utility

• NG-CC|CCS CF is interpolated between NG-CT and NG-CC as a f(var OpEx)

[5] M. Pellow, J. Eichman, J. Zhang, O. Guerra. Valuation of Hydrogen Technology on the Electric Grid Using Production Cost Modeling. (forthcoming) NREL 2020.

Annual storage cycling for a LDES system with 40% round trip efficiency[5].

LDES systems

Flexible power plants

12am

1am

6am

12pm

6pm

0%

20%

40%

60%

80%

100%Net discharge

Net charge

Sta

te o

f sto

rag

e (

%)

Ho

ur

of

da

y

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Natural gas price: $2.98/MMBTU

An

nu

al a

vera

ge c

apac

ity

fact

or

(%)

An

nu

al a

vera

ge c

apac

ity

fact

or

(%)

NREL | 10

Outline

• Methods

• Results


NREL | 11

First, let’s evaluate the Current Cost scenarios

Current Costs Future Costs

NREL | 12

24h(1d)

48h(2d)

72h(3d)

96h(4d)

120h(5d)

144h(6d)

168h(7d)

130

0

50

100

150

200

250

300

350

400

LC

OE

of p

ea

k p

ow

er

(20

18

$/M

Wh

)L

CO

Eo

f p

ea

k p

ow

er

(20

18

$/M

Wh

)

LCOE breakdown

Financing & taxes

O&M

Discharging capital

Storage capital

Charging electricity

Pumped Hydro Storage (PHS)

• Significant storage capital

• Financing the large upfront capital cost is a major LCOE contribution

• O&M increases as storage capital costs increases

HDV-PEM|Salt

• Low storage capital costs

• Energy dense fuel

• Minimal change in LCOE as duration increases

Scenario: Current Costs

LCOE breakdowns illustrate importance of low storage capital cost for longer durations

Storage capital cost is significant as

duration increases

LCOE breakdown

Financing & taxes

O&M

Discharging capital

Storage capital

Charging capital

Charging electricity

24h(1d)

48h(2d)

72h(3d)

96h(4d)

120h(5d)

144h(6d)

168h(7d)

333

0

50

100

150

200

250

300

350

400

LC

OE

of p

ea

k p

ow

er

(20

18

$/M

Wh

)L

CO

Eo

f p

ea

k p

ow

er

(20

18

$/M

Wh

)

Storage capital cost is minimal so LCOE

is insensitive to duration

NREL | 13

12h 18h 24h(1d)

30h 36h 42h 48h(2d)

HDV-PEM|Salt

HDV-PEM|Pipes

Stat-PEM|Salt

H2-CC|Salt

NG-CC

NG-CT

NG-CC|CCS

Eth-CC

PHS

A-CAES|Salt

D-CAES|Salt

VRB

P-TES

0

100

200

300

400

500

600

LC

OE

(20

18

$/M

Wh

)

Discharge duration at full power

• PHS becomes the lowest cost storage at 12 hours, consistent with what is expected for that duration on today’s grid

• Vanadium flow batteries (VRB) are just above D-CAES|Salt and A-CAES|Salt at 12 hours


“Calibrated CF” scenario LCOEs match expectations for 12h duration in current grid

NREL | 14

48h(2d)

72h(3d)

96h(4d)

120h(5d)

144h(6d)

168h(7d)

HDV-PEM|Salt

HDV-PEM|Pipes

Stat-PEM|Salt

H2-CC|Salt

NG-CC

NG-CT

NG-CC|CCS

Eth-CC

PHS

A-CAES|Salt

D-CAES|Salt

VRB

P-TES

0

200

400

600

800

1,000

1,200

LC

OE

(20

18

$/M

Wh

)


• Pumped hydro, A-CAES|Salt, P-TES, and VRB costs rise significantly with longer durations

• NG-CC, NG-CC|CCS, D-CAES|Salt, and geologic hydrogen storage are the lowest LCOE for long duration ratings


At 120 hours, D-CAES and NGCC|CCS are the lowest cost after NGCC

NREL | 15

Next, let’s evaluate the Future Cost scenario

Future costs reduction- Based from current cost & deployment- Projected to 200 GW future capacity- Technology learning rate

Power cost reductions Energy cost reductions

Current CostsCalibrated CF

Future CostsCalibrated CF

PEM-EC (high-P, AC)

HDV-PEM(AC)

Stat-PEM(AC)

CC

CT

NG-CC|CCS

PHS

CAES

VRB

P-TES

0

500

1000

1500

2000

2500

- 200 400 600 800 1,000 1,200 1,400 1,600

To

tal O

ve

rnig

ht C

ost (2

01

8$

/kW

-AC

)

Cumulative Installed Capacity (GW-AC)

Current costs

Future costs

H2-Salt

CAES-Salt

P-TES

PHS

VRB

Ethanol

H2-Pipes

0.1

1

10

100

- 5,000 10,000 15,000 20,000 25,000 30,000

To

tal O

ve

rnig

ht C

ost (2

01

8$

/kW

h-A

C)

Cumulative Installed Capacity (GWh)

Current costs

Future costs

NREL | 16

12h 18h 24h(1d)

30h 36h 42h 48h(2d)

HDV-PEM|Salt

HDV-PEM|Pipes

Stat-PEM|Salt

H2-CC|Salt

NG-CC|CCS

Eth-CC

PHS

A-CAES|Salt

VRB

P-TES

0

100

200

300

400

500

600

LC

OE

(20

18

$/M

Wh

)


• PHS and VRB are very competitive with PHS at 12-hour storage durations if future cost reductions are achieved

• Ethanol’s high variable OpEx results in a low capacity factor and high LCOE

Scenario: Future Costs

PHS, VRB, and A-CAES are the lowest cost for a 12h storage duration

NREL | 17

48h(2d)

72h(3d)

96h(4d)

120h(5d)

144h(6d)

168h(7d)

HDV-PEM|Salt

HDV-PEM|Pipes

Stat-PEM|Salt

H2-CC|Salt

NG-CC|CCS

Eth-CC

PHS

A-CAES|Salt

VRB

P-TES

0

200

400

600

800

1,000

1,200

LC

OE

(20

18

$/M

Wh

)


• Above 48 hours of storage, HDV fuel cells with geologic storage and NGCC|CCS have very similar LCOE due to low cost geologic storage

• HDV fuel cells provide lower capital cost with sufficient durability for this application

Scenario: Future Costs

At 120 hours, HDV-PEM|Salt and NG-CC|CCS have the lowest LCOE

NREL | 18

• With current costs, D-CAES and NG-CC|CCS provide the lowest LCOE

• If future capital costs are realized, geologic hydrogen and NG-CC|CCS are the most competitive

• Accounts for sensitivity to learning rate, future scale, and cost of energy input

• Without geologic storage or CCS: P-TES, Eth-CC, H2-pipes are lowest-cost options

• Uncertainty analysis shows significant overlap in technologies

Geologic H2 storage and NGCC|CCS provide lowest cost future options for 120h of flexible power

Current techCalibrated CF120h rating― with H2 co-production

Future techCalibrated CF120h rating― with H2 co-production

1st quartile most likely

1%ile

median 99%ile

3rd quartile

NREL | 19

Outline

• Methods

• Results


NREL | 20

Store-FAST Purpose

• Provide consistent framework for evaluation of utility scale flexible power

– Energy storage systems

– Flexible power generators

• Allow side-by-side evaluation of diverse technology options

• Incorporate use profiles informed by grid models

• Provide risk analysis based on for variability and uncertainty of inputs

NREL | 21

Caveats and Limitations

• The model attributes cost to energy and hydrogen co-products only. Revenue is not modeled from other possible value streams:

– ancillary services

– transmission deferment

• Model reflects an 85% renewable grid scenario.

• Model can use simple amortization of any refurbishment costs (it does not perform detailed capitalization of refurbishment costs such as stack replacements, battery replacements)

NREL | 22

Store-FAST Model Based on H2-FAST

User inputs– Capital costs (charging, storage, discharging)– Maintenance cost (fixed, variable)– System usage (capacity factors, system life)– Energy use (charging, fuel use, standing losses) – Energy prices (electricity, fuel, co-product value)– Financial parameters (e.g. depreciation schedule, interest rates, etc.)

Model computation framework: Generally Accepted Accounting Principles (GAAP)– Income statement projections (revenues, expenses, taxes)– Cash flow statement projections (cash on hand, capital expenditures, financing

transactions)– Balance sheet projections (assets, liabilities, equity)

Model outputs– Levelized cost of electricity (LCOE) – total, breakdown, distribution– Financial performance parameters (e.g. Internal rate of return, pay-back period,

break-even price of hydrogen)– Time series charts for all financial line items

NREL | 23

Model Use Step 1: Specify Tech Valuesin “Technology Specifications” tab

Global baseline values References

Storage duration rating (h) 120 1

Electricity for energy storage ($/kWh) 0.020 2

Natural gas ($/MMBTU) 2.98 38

Ethanol ($/gal) 2.22 13, 39, 40

CO₂ transportation and sequestration cost ($/tonne) 65 33, 34, 35

Key global inputs for all systems

HD

V-P

EM|S

alt

NG

-CC

|CC

S

Eth

-CC

PH

S

1,673 0 0 0

1 0 0 0

1 0 0 0

1.96 0 0.23 121.3

7,050,315 0 1 12,000,000

0.48 0 1 0.77

100% 0% 0% 100%

464 2543 1068 821

1 1 1 1

1 1 1 1

Charging base capacity (kW)

Charging scaling factor

Storage base capacity (kWh)

Storage scaling factor

Storage cost recovery at end of life (%)

Discharging base capacity (kW)

Discharging scaling factor

Discharging ($/kW-AC-out)

Tech name

Capital costs

Charging ($/kW-AC-in)

Effective storage ($/kWh-AC-out)

Capital costs on system level ($/kWh, $/kW)

Side by side systems

NREL | 24


HD

V-P

EM|S

alt

NG

-CC

|CC

S

Eth

-CC

PH

S

12.8 0 0 0

1.50% 0 0 0

0.0013 0 0 0

1.50% 1.50% 1.50% 1.50%

12.8 27.2 13.9 12.5

1.5% 1.5% 1.5% 1.5%

0.0028 0.00576 0.00251 0.0003

Charging O&M

Storage O&M

Discharging O&M

Variable

Tech name

Other ($/kWh_AC_out)

Fixed

O&M (labor, maintenance items) ($/kW_AC_out_y)

Property tax, insurance, licensing, permitting (% of cap cost)

Operations & maintenance (O&M) costs

Fixed

Maintenance, property tax, insurance, licensing, permitting (% of cap cost)

Other ($/kWh-AC-in)

O&M (labor, maintenance items) ($/kW_AC_in_y)

Property tax, insurance, licensing, permitting (% of cap cost)

Fixed

Variable

O&M specifications fixed, variable

NREL | 25


HD

V-P

EM|S

alt

NG

-CC

|CC

S

Eth

-CC

PH

S

2.86 0.00 0.00 1.23

0 0.007124 0 0

0 0 0.07608 0

0 0.000374 0 0

0.0% 0.0% 0.0% 0.0%

0.00000 0.000 0.000 0.000

0 0 0 1

1 2 2 1

30 30 30 30

100,000 100,000 100,000 100,000

Standing losses & auxiliaries

Others

Primary energy use

System operations

Tech name

Is sytem reversible? (1=yes,0=no)

Energy storage or flexible generator (1=e.store, 2=flex.gen.)

System life (years)

System power output rating (kW-AC)

Electricity use for power generation (kWh_AC_in/kWh_AC_out)

Natural gas use for power generation (MMBTU/kWh_AC_out)

Ethanol use for power generation (gal/kWh_AC_out)

CO₂ to for sequestration (m.tonnes/kWh_AC_out)

Auxiliary power (kW/kW_power_generation)

Adjustment for storage daily losses (kW/kWh_stored_energy)

Feedstock use per kWhelectricity, natural gas, ethanol, CO2 byproduct, H2 co-product

Other system inputsSystem type, life, power generation capacity

NREL | 26


HD

V-P

EM|S

alt

NG

-CC

|CC

S

Eth

-CC

PH

S

56.4 0 0 0

0 0 0 0

5% 0 0 0

Feedstock & product valuation References

Electricity for H₂ co-production scenarios ($/kWh) 0.035 1, 2

Hydrogen co-production value ($/kg) 2.50 26, 42

Tech name

% system idle time allowance for co-production

Electricity use for H₂ co-production (kWh_AC_in/kg_H₂_out)

H₂ coproduction parameters

Allow H2 co-production? (1=yes, 0=no)

Other system inputsSystem type, life, power generation capacity

NREL | 27

Model Use Step 2: Specify Sensitivitiesin “Sensitivity Parameters” tab

Range used for tornado charts and for triangular distributions for Monte Carlo

Min Baseline Max References

Storage duration rating (h) 72 120 168 1

Energy costs

Electricity for energy storage scenarios ($/kWh) 0.010 0.020 0.030 2

Natural gas ($/MMBTU) 2.383 2.98 3.505 38

Ethanol ($/gal) 1.18 2.22 2.66 13, 39, 40

CO₂ transportation and sequestration cost ($/tonne) 27 65 125 33, 34, 35

Hydrogen coproduction related

Electricity for coproduction scenarios ($/kWh) 0.025 0.035 0.045 1, 2

Hydrogen coproduction value ($/kg) 1.74 2.50 3 26, 42

Capital related

Power capital ±% -10.0% 0.0% +10.0%

Energy capital ±% -10.0% 0.0% +10.0%

Other parameter sensitivities

Recharge capacity factor ±% -5.0% 0.0% +5.0%

Power generation capacity factor ±% -5.0% 0.0% +5.0%

Relative efficiency ±% -10.0% 0.0% +10.0%

System life ± years -5 0 +5

NREL | 28

Select system to plot

HDV-PEM|Salt

LCOE @ Baseline Scenario

$365/MWh

Update Tornado & Duration Plots: Run time ~2min

Net Debt Financing Expense

Net Equity Financing Expense

Capital Gains Taxes Payable

Income Taxes Payable

Discharging O&M

Storage O&M

Charging O&M

Discharging Cap

Storage Cap

Charging Cap

Electricity

Monetized Tax Losses

Sale Of Non-Depreciable Assets

-100

-50

0

50

100

150

200

250

300

350

400

8 24 40 56 72 88 104 120 136 152 168

LCO

E ($

/MW

h)

Duration rating (h)

Cost Break-Down: HDV-PEM|Salt

Model Use Step 3: Click Update Buttonin “Technology Specifications” tab

365336

340

356

355

361

361

361

363

394

396

380

377

370

369

370

367

300 310 320 330 340 350 360 370 380 390 400 410

Electricity cost(1, 2, 3 ¢/kWh)

Round trip efficiency(38.5, 35, 31.5 %)

System life(40, 30, 20 years)

Charging CF(25.6, 24.3, 23.1 %)

Power CapEx(2248, 2291, 2334 $/kW)

Duration rating(72, 120, 168 h)

Power generation CF(9.4, 9, 8.5 %)

Energy CapEx(1.34, 1.48, 1.63 $/kWh)

HDV-PEM|Salt

LCOE $/MWh

Scenario Sensitivities:

HDV-PEM|Salt

HDV-PEM|Pipes

Stat-PEM|Salt

H2-CC|Salt

NG-CC

NG-CC|CCS

Eth-CC

PHS

A-CAES|Salt

D-CAES|Salt

VRB

P-TES

31.4 71.1

0.7 50.5 88.2

-

200

400

600

800

1,000

1,200

0 24 48 72 96 120 144 168 192 216

Duration rating (h)

LCO

E ($

/MW

h)

Total LCOE vs. Technology

NREL | 29

Select system to plot

HDV-PEM|Salt

LCOE @ Baseline Scenario

$365/MWh

Update Tornado & Duration Plots: Run time ~2min

Net Debt Financing Expense

Net Equity Financing Expense

Capital Gains Taxes Payable

Income Taxes Payable

Discharging O&M

Storage O&M

Charging O&M

Discharging Cap

Storage Cap

Charging Cap

Electricity

Monetized Tax Losses

Sale Of Non-Depreciable Assets

-100

-50

0

50

100

150

200

250

300

350

400

8 24 40 56 72 88 104 120 136 152 168

LCO

E ($

/MW

h)

Duration rating (h)

Cost Break-Down: HDV-PEM|Salt

Model Use Step 4: Select System to Examinein “Technology Specifications” tab

365336

340

356

355

361

361

361

363

394

396

380

377

370

369

370

367

300 310 320 330 340 350 360 370 380 390 400 410

Electricity cost(1, 2, 3 ¢/kWh)

Round trip efficiency(38.5, 35, 31.5 %)

System life(40, 30, 20 years)

Charging CF(25.6, 24.3, 23.1 %)

Power CapEx(2248, 2291, 2334 $/kW)

Duration rating(72, 120, 168 h)

Power generation CF(9.4, 9, 8.5 %)

Energy CapEx(1.34, 1.48, 1.63 $/kWh)

HDV-PEM|Salt

LCOE $/MWh

Scenario Sensitivities:

Selected system will also populate baseline details in the “Interface” and “Report Tables” tabs. (for system of

baseline duration rating)

NREL | 30

HDV-PEM|Salt

HDV-PEM|Pipes

Stat-PEM|Salt

H2-CC|Salt

NG-CC

NG-CC|CCS

Eth-CC

PHS

A-CAES|Salt

D-CAES|Salt

VRB

P-TES

0 100 200 300 400 500 600 700 800 900 1000

LCOE $/MWh

Monte-Carlo Technology Cost Distributions

Model Use Step 5: Run Monte Carloin “Sensitivity Parameters” tab

Click “Update Monte Carlo Analysis” macro button. This step takes ~30-60 min.

Update Monte Carlo AnalysisViolin Plots: Run time ~1h

most likely

min

max

Tech Name

Violin plots:multi histogram plots

NREL | 31

Model Is Self-Documented

Description tab: Tabs descriptionStep-by step walkthrough

All inputs include pop-up descriptions when user clicks on a cell.

NREL | 32

Model Demonstration: Adding H2 Coproduction

NREL | 33

Example Compatible Systems With Model

Energy storage type Currently in base case

Batteries (any chemistry)

Liquid air storage

Gravity energy storage

Ammonia*

Hydrogen* √

Vanadium flow batteries √

Pumped hydro √

Adiabatic CAES (using thermal storage) √

Thermal √

*Model allows for modelling of hybrid systems e.g. energy storage with hydrogen co-production.

NREL | 34

Example Compatible Systems With Model

Flexible generator types Currently in base case

Conventional hydro

Geothermal

Turbines + renewable methane

Nuclear (if dynamics allow)

Turbines + CCS √

NG-fired CAES √

NG-fired Turbines √

Ethanol-fired Turbines √

www.nrel.gov

Thank You

This work was authored by the National Renewable Energy Laboratory, operated by Alliance for Sustainable Energy, LLC, for the U.S. Department of Energy (DOE) under Contract No. DE-AC36-08GO28308. Funding provided by U.S. Department of Energy Office of Energy Efficiency and Renewable Energy Fuel Cell Technologies Office. The views expressed in the article do not necessarily represent the views of the DOE or the U.S. Government. The U.S. Government retains and the publisher, by accepting the article for publication, acknowledges that the U.S. Government retains a nonexclusive, paid-up, irrevocable, worldwide license to publish or reproduce the published form of this work, or allow others to do so, for U.S. Government purposes.

Model link: https://www.nrel.gov/storage/storefast.html


36OFFICE OF ENERGY EFFICIENCY & RENEWABLE ENERGY HYDROGEN AND FUEL CELL TECHNOLOGIES OFFICEU.S. DEPARTMENT OF ENERGY

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37OFFICE OF ENERGY EFFICIENCY & RENEWABLE ENERGY HYDROGEN AND FUEL CELL TECHNOLOGIES OFFICEU.S. DEPARTMENT OF ENERGY

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