2. 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
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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
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Shell’s 20-F for the year ended December 31, 2013 (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, 17 June 2014
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. Main Points
• Why IH2 technology?
• Integration with existing assets
• Commercialization Process
• Product Quality Update
• Executive Summary
4. Why IH2 Technology?
• Self-sufficient, self-contained and self-sustaining
• Feedstock flexible, product yields 67-172 gal/ton (MAF)
Spans gasoline, jet and diesel range
No detectable oxygen or TAN
• High GHG reductions
• Integrates commercially proven equipment; Market Ready
• Attractive economics (standalone or co-locate with existing assets)
• Improved catalysts enhanced product yield & quality
• Available exclusively from CRI Catalyst Company
5. Why IH2 Technology?
Biogenic CO2
Hi Pressure
Steam
Distilled
Hydrocarbon
Clean Water
Fertilizer
BioChar
Feed
City Waste
Crop Residue
Wood/Forest
Residue
Energy Crops
Algae
Products
2) Fluidized Bed
Proprietary
Catalyst System
Renewable H2
340-470C
<500psig
4) SMR C1-C3 Gas
1st Stage 2nd Stage
1) Feed Conditioning
Sizing , Drying & Feeding
3) Fixed Bed
Proprietary
Catalyst System
Renewable H2
<500psig
Renewable H2
Process
5) Cyclones
Gasoline, Jet and Diesel
Hydrocarbons (67-172 gal/ton)
R100 Regular Gasoline (Wood)
R100 Intermediate Gasoline (Wood)
R100 Diesel (Wood)
6. Integration - Refinery
Option 1: Full Standalone
Location Flexibility, Minimum Environmental Impact
Maximum GHG reduction
Lowest CI product
Highest Capital Cost
No Fixed Cost Synergy
Option 2: Integrated with Refinery HT
Minimum Environmental Impact
Lowest CI product
Maximum GHG reduction
Lower Capital Cost
Some Fixed Cost Synergy
Option 3 Integrated with Refinery H2
Higher Environmental Impact
Reduced GHG reduction
Higher CI product
Lowest Capital Cost
Capital ~25% lower than base case
9/23/2014 6
7. Cane Trash/
Sugar Cane Tops
Integration – Sugar Mill
IH2 Bagasse Unit
Sugar
Cane
Sugar
Factory
Enhanced
Energy
Integration
Hot water
Char
Co-Gen HP Steam
9/23/2014 7
Sale to grid
Sugar
Molasses
Fuels
Boiler
LP Steam
8. Primary Product(s)
Growth Harvest Extraction
Residues
HP Steam or HP Steam to Power
CO2
NH3 / S / Ash
LP Steam / Hot Water
9/23/2014 8
Fuel
100 gal/ton MAF
70% gasoline/ 30%
diesel
Integration – Algae Facility
9. Growth Harvest Extraction
Whole Algae
HP Steam or HP Steam to Power
CO2
NH3 / S / Ash
LP Steam / Hot Water
9/23/2014 9
Fuel
157 -172 gal/ton MAF
(50% gasoline/
50% diesel)
Integration – Algae Facility
10. Integration – Paper Mill, “Soft Assets”
• Wood Supply System
– Procurement staff & buyer networks/intellectual capital
– Fiber Supply Agreements
– Landowner data: US RFS-2 “chain-of-custody” requirements
• Contract data – ownership & legal description
• Load tickets – link delivered loads to harvest location
• Harvest location maps – spatial data
• Fiber Accounting & Information Systems Integration
• HSE Systems
– Air & water permits
– Sampling & reporting structure/agency interaction
9/23/2014 CRI & SHELL CONFIDENTIAL
INFORMATION
10
11. Integration – Paper Mill, “Hard Assets”
Heat
LP Steam / Heat
Power
9/23/2014 CRI & SHELL CONFIDENTIAL
INFORMATION
11
Paper Process
Digestion, refining,
washing, paper machines Paper
Fuel
90 gal/ton MAF
65% gasoline/ 35%
diesel
Char
Boiler/
Co-Gen
Wood Yard
Handling, storage,
chipping, drying,
hammer milling
LP Steam or Power
to grid
Biomass Feedstock
Chips
Char
Multiple uses for low-grade heat or power
Soft Assets
LP Steam / Power
12. 0.02L/day
Bangalore 1L/week
Chicago, Bangalore
22L/day
Chicago
2000L/day
NanoScale EE HT tools
GTI/CRI Design Basis
Commercially Engineered
Commercially Fabricated
1st Stage System
2nd Stage System
On line analytical suite
Up to 16 runs/day/system
Chicago Unit
GTI Design Basis
GTI Built
Bangalore Unit
GTI/CRI Design Basis
Commercially Engineered
Commercially Fabricated
Mixture online/offline
Up to 3 runs/week
GTI Design Basis
Commercially Engineered
Commercially Fabricated
Mixture Online/Offline
Up to 1 run/week
GTI/CRI Design Basis
Commercially Engineered
Mixture Online/Offline
Up to 3 runs/month
Commercialization Process
14. Product Quality – MBU Scale
Improve product yield, appearance and quality
Total Liquid Product
2nd Gen Catalysts Lab Scale
Hydrocarbon
Water
Total Liquid Product
1st Gen Catalysts Lab Scale
Hydrocarbon
Water
Gas/Jet/Diesel Product
3rd Gen Catalysts Lab Scale
4Q09 “R5” 3Q10 “R25” 2Q12 “R60+”
Jet/Diesel Product
4th Gen Catalysts Lab Scale
1Q14 “R100”
15. Product Quality – Pilot Scale
Gasoline Product
3rd Gen Catalyst
Drop In / Tank Ready
US R100 Quality (RBOB)
Jet/Diesel Product
3rd Gen Catalyst
US R100 Diesel
Water Product
3rd Gen Catalyst
Clean, No Carbon
Contains NH3/H2S
(lacks commercial
design water clean up )
16. Product Quality Summary
US
• Gasoline (from wood):
R100 Meets ASTM D-4814-10b
~86 Octane
S < 15-ppm
Fully renewable premium RBOB
• Diesel (from wood)
R100 Meets ASTM D-975-11
Cetane Number 44
S < 10-ppm
Europe:
• Petrol (from wood)
Petrol (from wood)
EN 228: Petrol – Jan 2009
Octane Low
S ~10-ppm
• Diesel (from wood)
EN 590:2009+A1:2010
Cetane # Low
S ~15-ppm
• 3rd Party Testing Underway in 2H2014
• More Upgrading Wood Product for EU
Specs
17. Executive Summary
• Self-sufficient, self-contained and self-sustaining
• Feedstock flexible, product yields 67-172 gal/ton (MAF)
Spans gasoline, jet and diesel range
No detectable oxygen or TAN
• High GHG reductions
• Integrates commercially proven equipment; Market Ready
• Attractive economics (standalone or co-locate with existing assets)
• Improved catalysts enhanced product yield & quality
• Available exclusively from CRI Catalyst Company
18. Thank You
Learn more at
http://www.cricatalyst.com/catalysts/renewables.html
9/23/2014 18
Editor's Notes
Stand Alone or,
Reduced capital cost options
Existing hydrogen supply
Idled assets or Rx’s that could be suitable for Second Stage
Facilities have existing storage / distribution network for liquid hydrocarbons
Provides Refiners with control to assure their supply of renewable fuel to meet mandate “License to operate”
RFS-2 “each producer and importer of gasoline and diesel determines the minimum volume of renewable fuel that it must ensure is used in its transportation fuel,” according to EPA.
Case could be made that the light ends from IH2 still end up being green moles of H2 because they came from a green source, but whether that would be “allowed” or could be counted/metered is debatable at this stage.
Stand Alone or,
Reduced capital cost options
Existing hydrogen supply
Idled assets or Rx’s that could be suitable for Second Stage
Facilities have existing storage / distribution network for liquid hydrocarbons
Provides Refiners with control to assure their supply of renewable fuel to meet mandate “License to operate”
RFS-2 “each producer and importer of gasoline and diesel determines the minimum volume of renewable fuel that it must ensure is used in its transportation fuel,” according to EPA.
Case could be made that the light ends from IH2 still end up being green moles of H2 because they came from a green source, but whether that would be “allowed” or could be counted/metered is debatable at this stage.
Scenario 1. Integrating IH2 facility with algae facility using only post-extracted residues to make hydrocarbon fuels. You can still extract algae for your primary products as normal. The hydrocarbon yield from using residues only is approx. 100 gal/ton on MAF basis. CO2, NH3, S and hot water can be used to grow algae and the HP steam can be used for the whole algae facility. This will improve the site margin by monetizing the residues.
Scenario II: Using the whole algae as feedstock for IH2 process. In this case the yield will be higher at as I mentioned 157 – 172 gal/ ton. The economics will have to be balanced depending on the value that you receive from your primary products.
Soft Asset Integration represents significant value for Pulp & Paper co-location with IH2. Wood supply systems are complex. Procurement, contracting, and managing short-mid-and-long-term fiber supply agreements requires infrastructure and software that integrates accounting & payment processes, contract administration, and business processes. These processes run behind the scenes of truckloads of wood being delivered to the facility. Purchasing wood not only relies on knowledge and active participation in the local and regional timber markets, but also relationships with landowners and wood buyers. These are critical to managing inventories and optimizing pricing. The information technology systems behind the scenes integrate the scale-house data with the contract data, and purchase price to ensure the right landowner is paid the right amount on time for the products delivered from his property and that the inventory of wood at the facility is updated and kept current. These systems have evolved with the industry and many are “custom built” for a particular location – the value of an ongoing wood supply system should not be taken for granted. Environmental permits also represent a huge potential value. Many of these permits have also “grown” with the facility and often have “grandfathered” TMDL’s and Permit limits etc. that would be difficult to attain under current regulations – so amendments are typical with changing regulations . Each location certainly has its own set of limitation & opportunities, but the high level of sampling and environmental compliance required at paper mills has resulted in a culture of safety and environmental awareness, sampling, reporting & direct interaction with the regulatory agency personnel – these permits and processes can often be more easily amended than developed from the ground-floor.