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Introduction of Hydrogen Technologies to Ramea Island
Introduction of Hydrogen
Technologies to Ramea Island
Morel Oprisan
IEA Wind KWEA Joint Workshop
April, 2007 2
1. Ramea Island
2. Background
3. Hydrogen Integration
4. Project Phases
5. Project Partners
6. Equipment Sizing
7. Project Timeline
8. Expected Performance
Presentation Overview 3
1. Ramea Island
Island of Newfoundland
World class wind resource
Potential for many 100s of MW
Ramea Island
Not connected to Island grid
Ferry access only
~ 350 customers
1,078 kW peak load (winter)

Ramea Island
Newfoundland 4 +12 months of successful operation: CF = 0.33 Wind production ~ 1 million kWh electricity / yr Diesel fuel savings ~ 10% ~ 750 tonnes / yr GHG emissions reductions Improved air quality
2. Background Commissioning of first Wind-Diesel
demonstration project in Canada in
2004 NRCans unique control
system integrates wind
with existing diesel generation
Windmatic 65 kW
Turbine
Town of Ramea 5
Current Situation on Ramea Installed wind capacity: 6 x 65 kW = 390 kW Real wind capacity: 390 kW x 0.33 = 129 kW Total energy produced = 4,201 MWh in 2005 Diesel / Wind (90% / 10%)
Wind-Diesel System in Ramea,
Newfoundland Installed diesel capacity:
3 x 925 kW = 2,775 kW Often one only diesel generator
running at 300 kW Excess wind energy is dumped,
therefore, storage would increase
wind penetration 6
Potential for Commercialization
Existing NL Hydro isolated diesel systems:
Significant potential for deployment in remote communities
in Canada and around the world 7
3. Hydrogen Integration 8
A.
Feasibility study Modelling and feasibility study done by NRCan Goals: Establish potential for hydrogen storage and
contribute to
equipment sizing
B.
Implementation on Ramea Led by Newfoundland and Labrador Hydro Other Canadian Federal Government funding:
$3M CAD confirmed, $1.7M CAD pending
4. Project Phases 9
5. Project Partners
FRONTIER
POWER
SYSTEMS 10
Hydrogen Generator
Hydrogen Storage /
Compression
Electrolyzer
Wind Capacity
Control System
6. Equipment Sizing
Relationship
between
components is
complex 11
Hydrogen Generator 12 Known, reliable internal combustion
technology Lower cost than fuel cell Current fuel cell
technology not
mature enough Previous operator
experience
Hydrogen Generator
HEC 250 kW H
2
Genset 13 250 kW (4+1 engines, 4 x 62.5 kW) Supplied by Hydrogen Engine Center Canada Based on 4.9 L Ford engines Testing for
performance, emissions,
modelling parameters in
Spring 2007 Post-testing: Loaned and
delivered to NL Hydro
Hydrogen Generator
Interior View of HEC
250 kW H
2
Genset 14
Other Equipment 15 Conventional H
2
storage leaves
smaller environmental footprint
than batteries Looking at long-term storage
applications towards a H
2
economy Complementary to NRCans
existing R&D into advanced
utility-sized batteries
(e.g. VRB and NaS)
Hydrogen Storage
Sodium Sulphur
Battery 16
Preliminary Estimate Work backwards from genset
requirement to determine how
large storage needs to be Genset H
2
consumption: 250 Nm
3
/hr
Hydrogen Storage / Compression Min genset autonomy: 8 hours
8 hr x 250 Nm
3
/hr

2000 Nm
3
required storage At 6700 psi (typical steel storage), require
6837 L H
2
0 equivalent volume
9 x 19-ft cylinders
H
2
Storage 17
Preliminary Estimate Work backwards from storage requirement to
determine minimum electrolyzer H
2
production Maximum time to fill H
2
storage: 24 hrs
2000 Nm
3
/ 24 hrs = 79 Nm
3
/hr
+ additional capacity
~ 90 m
3
/hr electrolyser
Electrolyzer
Hydrogenics Electrolyzer 18
Wind Capacity
Preliminary Estimate Work backwards from electrolyzer electrical
requirement to determine minimum wind capacity (kW) Assume CF = 0.33
0
200
400
600
800
1000
0
10
20
30
40
50
60
70
80
90
100 110 120 130
Electrolyser Output (Nm
3
/ hr)
Electrical Power
Required (kW)
~ 1500 kW planned installed wind capacity 19
Control System Control system must work with each
components control system and with the
existing wind-diesel control system
Enercon E33 Turbine Must optimize each components
production so that overall wind
penetration is maximized 20
August 2007: Project Definition & Sanctioning Committed funding finalized & funding contracts completed Project partnerships established and agreements in place System modelling, component sizing and project design
December 2008: Project In Service Finalize equipment selection and design Procure equipment Control system design, testing, development and
commissioning
December 2011: Three Years Operations & Reporting
7. Project Timeline 21
8. Expected Performance Preliminary
performance will be
optimized through
feasibility study Round trip efficiency
expected to be
approximately 25%
90%
Storage +
Decompression
25%
Approximate
Round Trip
Efficiency
35%
Hydrogen
Internal
Combustion
80%
Electrolysis +
Compression
Approximate
Efficiency
Component 22
Thank You
Morel Oprisan
Deputy S&T Director, Renewable Energy Technologies
morel.oprisan@nrcan.gc.ca