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IH2 Technology Economics Update Pat Leung, CRI Catalyst Company, 910 Louisiana, Houston, TX 77002
ARTC Presentation
6 March 2013
Disclaimer
This presentation contains forward-looking statements concerning the financial condition, results of operations and businesses
of Royal Dutch Shell. All statements other than statements of historical fact are, or may be deemed to be, forward-looking
statements. Forward-looking statements are statements of future expectations that are based on management’s current
expectations and assumptions and involve known and unknown risks and uncertainties that could cause actual results,
performance or events to differ materially from those expressed or implied in these statements. Forward-looking statements
include, among other things, statements concerning the potential exposure of Royal Dutch Shell to market risks and statements
expressing management’s expectations, beliefs, estimates, forecasts, projections and assumptions. These forward-looking
statements are identified by their use of terms and phrases such as ‘‘anticipate’’, ‘‘believe’’, ‘‘could’’, ‘‘estimate’’, ‘‘expect’’,
‘‘goals’’, ‘‘intend’’, ‘‘may’’, ‘‘objectives’’, ‘‘outlook’’, ‘‘plan’’, ‘‘probably’’, ‘‘project’’, ‘‘risks’’, ‘‘seek’’, ‘‘should’’, ‘‘target’’, ‘‘will’’ and
similar terms and phrases. There are a number of factors that could affect the future operations of Royal Dutch Shell and could
cause those results to differ materially from those expressed in the forward-looking statements included in this presentation,
including (without limitation): (a) price fluctuations in crude oil and natural gas; (b) changes in demand for Shell’s products; (c)
currency fluctuations; (d) drilling and production results; (e) reserves estimates; (f) loss of market share and industry
competition; (g) environmental and physical risks; (h) risks associated with the identification of suitable potential acquisition
properties and targets, and successful negotiation and completion of such transactions; (i) the risk of doing business in
developing countries and countries subject to international sanctions; (j) legislative, fiscal and regulatory developments
including regulatory measures addressing climate change; (k) economic and financial market conditions in various countries
and regions; (l) political risks, including the risks of expropriation and renegotiation of the terms of contracts with governmental
entities, delays or advancements in the approval of projects and delays in the reimbursement for shared costs; and (m)
changes in trading conditions. All forward-looking statements contained in this presentation are expressly qualified in their
entirety by the cautionary statements contained or referred to in this section. Readers should not place undue reliance on
forward-looking statements. Additional factors that may affect future results are contained in Royal Dutch Shell’s 20-F for the
year ended December 31, 2011 (available at www.shell.com/investor and www.sec.gov ). These factors also should be
considered by the reader. Each forward-looking statement speaks only as of the date of this presentation, 6 March 2013
Neither Royal Dutch Shell nor any of its subsidiaries undertake any obligation to publicly update or revise any forward-looking
statement as a result of new information, future events or other information. In light of these risks, results could differ materially
from those stated, implied or inferred from the forward-looking statements contained in this presentation.
3/21/2013 2
Main Points
• Introduce Gas Technology Institute (GTI) and CRI Catalyst (CRI)
• What is the IH2 process?
• Why does IH2 technology transform renewable fuels processing?
• IH2 process economics
• Where is IH2 in the commercial deployment?
3/21/2013 3
Technology Heritage - GTI Snapshot
• Not-for-profit gas research & services organization founded as IGT in 1941
• Capabilities that span the natural gas value chain
• Current focus is in diversified energy solutions
• Facilities – 18 acre Chicago campus
– 28 specialized labs totaling 200,000 ft2
• Staff of 250
• >1,200 patents and 750 licenses
• ~500 products commercialized with partners
3/21/2013 4
Pilot Scale Gasification Campus Energy & Environmental Technology Center
Offices& Labs
CRI is the partner for IH2
Technology Heritage - CRI Snapshot
• Catalyst Business with 50+ year history
• Houston based global business – Houston (One Shell Plaza)
– London (Fareham)
– Singapore (Tiong Bahru)
• Research & Technology Facilities – Amsterdam
– Bangalore
– Houston
• Manufacturing Facilities – US (3)
– Germany
– Belgium
3/21/2013 5
What is the IH2 Process?
• The IH2 process uses catalysts, hydrogen and heat to cost-effectively
convert a wide variety of biomass directly into high purity hydrocarbon
“drop in” fuels (i.e. B100) and/or high quality blend stock (e.g. >B50)
3/21/2013 6
• The IH2 process takes only minutes to convert biomass to
hydrocarbons—Nature requires millions of years…
• The IH2 process can be integrated into existing refinery, mill, ethanol
plant, agricultural, or recycling operations to create higher value from
biomass than afforded by heat and electrical power sales (NA basis)
• The IH2 process is NOT Gasification/Fischer Tropsch
2) Fluidized Bed
Proprietary Catalyst
Renewable H2
340-470C <500psig
1) Feed Conditioning Sizing , Drying & Feeding
1st Stage 2nd Stage
3) Fixed Bed
Proprietary Catalyst
Renewable H2
370-400C <500psig
HDO’d Vapors
4) SMR C1-C3 Gas Renewable H2
Process
3/21/2013 7
IH2 Process (Simplified, Stand Alone)
Distilled Hydrocarbon
Hi Pressure Steam
Clean Water
Fertilizer
BioChar
Biogenic CO2
Crop Residue
City Waste
Wood/Forest Residue
Energy Crops
Algae
Gasoline, Jet and Diesel Range HCs B100 Regular Gasoline (Wood) B100 Intermediate Gasoline (Wood) B60 + Diesel (Wood)
Feed
Products
Not Gasification / Fischer Tropsch!
Technology Differentiators
• Fungible, high purity hydrocarbon fuel and/or blend stock products
- Gasoline produced from wood passes ASTM specs (i.e. B100) for economy & mid octane
- Diesel produced from wood too aromatic, currently ~B60, target is to get to B100
- Diesel produced from whole algae likely B100 (in testing)
• Nearly carbon neutral*
• Feedstock flexible with high product yields (67-157 US gal/US ton MAF)
• Attractive economics (~ $2/gal for 500 dry MT/day wood feed USGC pricing) - Low capex (only 4 major process steps, low pressure, non corrosive) - Low opex (predominated by feedstock)
• Exothermic process with 72% - 86% bioenergy recovery (wood)
• No engineering miracles required! Ready for market
*93% - 98% GHG reduction per Professor David Shonnard at MTU: http://services.lib.mtu.edu/etd/THESIS/2012/ChemicalEng/maleche/thesis.pdf
3/21/2013 8
Techno-economic Analysis by NREL
• NREL (National Renewable Energy Laboratory) is a primary
laboratory of the US Department of Energy (DOE) for Renewable
Energy and Energy Efficiency research & development
• Comparing economics of different technologies on a similar set of
assumptions such as: - nth plant
- 2000 mt of dry biomass per day
- 30-year plant life
- 40% equity financing with 10% IRR
- 60% debt financed at 8% interest rate
• MFSP (Minimum Fuel Selling Price) can then be used to assess the
cost-competitiveness of each technology
3/21/2013 9
4.7
17.7
6.8
44.0
36.6
Feed
1st Stage HP/ 2ndStage HC
Fractionation
HMU
Utilities & Contingency@ 35%
Installed Equipment Costs $112.6mln
112.6
5.7 11.7
102.7
Installed EquipmentCosts
Land/Develop
Permits & S/U
Standard ProjectAdd-In's**
Total Capital Investment $232.8mln
91.31
7.8
2.14
17.3
5.9
29.6
Wood $71.97/dry ton
Other Op Costs: Catalyst,Disposal, etc.
Fixed Cost
Depreciation
Avg Income Tax
Avg ROI
Operating Costs Total $1.60/gal*
*Includes $0.093/gal coproduct credit
** Prorated Expense (10%), H O & Construction (20%), Field
Expense (10%), Working Capital (10%) , Project Contingency (30%)
• Stand Alone/Green Field (US Gulf Coast basis)
• 2000mt/d wood (30% moisture fed, dried to 10% moisture at 1st stage)
• Equipment cost - HMU is largest @ $44mln ~40% TIC
• Feed Stock ~55% of Operating Cost
• No subsidies, tax, RIN or carbon credits included!
• Minimum Fuel Selling Price – $0.423/L (2007) $0.465/L (2012)
$1.60/gal $1.76/gal
• Refinery Synergy w/Refinery H2 Supply
• Estimated MFSP $0.359/L (2007) $0.394/L (2012)
$1.36/gal $1.49/gal
• NREL TIC validated by KBR pointing to higher HMU cost
• Opex validated by prospective clients
IH2 Process Estimates (USGC) NREL 06/11 Basis
3/21/2013 10
http://www.osti.gov/bridge/servlets/purl/1059031/1059031.pdf
4.7
17.7
4.0
55.0 2.8
2.8
40.5
Feed
1st Stage/2nd Stage
Fractionation
HMU
Ammonium Sulfate
Absorption/Stripping
Utilities & Contingency@ 35%
Installed Equipment Costs $127.5mln
** Prorated Expense (10%), H O & Construction (20%), Field
Expense (10%), Working Capital (10%) , Project Contingency (30%)
• Stand Alone/Green Field (US Gulf Coast basis)
• 2000mt/d wood (30% moisture fed, dried to 10% moisture at 1st stage)
• Equipment cost - HMU is largest @ $55mln ~45% TIC
• Feed Stock ~55% of Operating Cost
• No subsidies, tax, RIN or carbon credits included!
• Minimum Fuel Selling Price – $0.433/L (2007) $0.476/L (2012)
• $1.64/gal $1.80/gal
• Refinery Synergy w/Refinery H2 Supply
• Estimated MFSP $0.359/L (2007) $0.394/L (2012)
$1.36/gal $1.49/gal
• KBR FEED underway (FEL-2 complete , FEL-3 underway)
• Opex validated by prospective clients
IH2 Process Estimates (USGC) NREL 09/12 Basis
3/21/2013 11
127.5
6.3 13.2
116.5
Installed EquipmentCosts
Land/Develop
Permits & S/U
Standard ProjectAdd-In's**
Total Capital Investment $263mln
91.31
7.8
2.14
17.3
5.9
29.6
Wood $71.97/dry ton
Other Op Costs: Catalyst,Disposal, etc.
Fixed Cost
Depreciation
Avg Income Tax
Avg ROI
Operating Costs Total $1.64/gal*
*Includes $0.1884/gal coproduct credit
• Bench Scale
– Since 02/2009 @ 0.5kg/hr
• Pilot Scale
– Since 02/2012 @ 50kg/d
– Confirmed bench scale results
– Producing fuels for EPA Registration
– Producing fuels for ASTM Qualification
– Wood derived gasoline is B100!
• Pre Commercial Scale
– BDEP for 5mt/d cellulose done
– 1st demonstration license awarded 12/2012, more expected in Q1 2013
• Commercial Scale
– KBR is CRI’s exclusive engineering partner for BDEP >330 t/d
– BDEP 500 & 1000mt/d wood (FEL-2 and -3 underway)
– Target Q1 2014 for full scale commercial deployment
IH2 Technology Deployment
12 3/21/2013
Commercial Timeline, Current Status
3/21/2013 13
1Q10
2Q10
3Q10
4Q10
1Q11
2Q11
3Q11
4Q11
1Q12
2Q12
3Q12
4Q12
1Q13
2Q13
3Q13
4Q13
1Q14
2Q14
3Q14
4Q14
Process
Variables and
Semi-
Continuous
Operation
Lab Scale Demo Scale Units Only (11 units)
(Brownfield Construction; Date Basic Engineering Starts) Full
Commercial
Construction
Basic/Detailed
Engineering
Construct 50kg/d
Pilot Plant
Receive Unit
Pilot Scale
Continuous Pilot
Plant Operation
Shake Down
Wood, 5-1000mt/d
Crop Residues, 5-10mt/d
Micro Algae, 5mt/d
Mixed Paper/OCC/Urban Wood, 5mt/d
Basic
Engin
eering
5m
t/d
Basic
Engin
eering
Began 5
00m
t/d
Basic
Engin
eering
Began 1
000m
t/d
Today
Executive Summary
The IH2 technology is
– a cost-effective process developed by GTI with US Dept of Energy
co-funding that converts biomass directly to high purity hydrocarbon
fuels and/or blend stocks using proprietary catalysts
– self-sufficient and self-sustaining with little unsustainable impact on
the surrounding environment needing only transport in/out of the site
– feedstock agnostic, able to consume broad range of biomass
straight, but feed can be mixed and changed routinely without
process refinement
– NOT gasification/Fischer-Tropsch
– nearly carbon-neutral (LCA >93% GHG* reduction)
– currently in basic engineering for multiple feed demonstrations
– available exclusively from CRI
14 3/21/2013
Thank You
3/21/2013 15
Learn more at
www.cricatalyst.com/renewables