G R O U P
Snamprogetti
Presentation to RICE
Snamprogetti’s Highlights
EST Technology
byRomolo Montanari
Snamprogetti S.p.A.
Viale De Gasperi,16 - 20097 San Donato Milanese – Italy
Snamprogetti 22
H
Giving life to your projects
The Parent Company
Snam Rete Gas S.p.A. EniPower S.p.A.Italgas S.p.A. Snamprogetti S.p.A. (*) Saipem S.p.A. (*)
Exploration & Production Gas & Power Refining & Marketing
Companies operating in Engineering and Oilfield Services respectively
(*)Divisions Subsidiaries
Snamprogetti 33
Snamprogetti Capabilities and Roles
Construction
Feasibility and ConsultingStudies
Basic Design
Procurement
Training
Commissioning and PlantStart-up
Detailed Engineering
Project Financing Assistance
Overall Project Management
RolesRoles
CapabilitiesCapabilities
Project Managing Contractor
Technology Supplier
Main Contractor
Snamprogetti 44
Experience
In 101 Countries since 1956In 101 Countries since 1956
Over 70 grass-roots plants(refining, petrochemical, gas processing),over 1,400 process units
74,500 km onshore pipelines designed21,500 km of submarine pipelines designed
Snamprogetti 55
Major Projects Under Way (1)
EPC• Visbreaker Tar Gasification PlantLocation: Sannazzaro de’ BurgondiClient: Eni Refining&Marketing divisionCapacity: Tar 1,200 t/d
ITALYITALY
• Green Stream Offshore Gas Pipeline Location: Mellitah to Gela (Italy) Client: Agip North Africa Technical Characteristics: 32”, 520 km Maximum Depth: 1,109 m
Detailed Engineering,Inspection of Supplies,
Supervision of Construction
Record of depth in relation to diameter
LIBYALIBYA
• Onshore gas treatment plantLocation: MellitahClient: Agip Gas B.V. Libyan BranchCapacity: 6,6 bcm/y
LSTK in J/V
Snamprogetti 66
Major Projects Under Way (3)
• Fourth, Fifth and Sixth LNG TrainLocation: Bonny IslandClient: Nigeria LNG LimitedCapacity: 4 million t/y each
LSTK in JV
NIGERIANIGERIA
QATARQATAR
• Fourth and Fifth LNG TrainLocation: Ras LaffanClient: Ras Laffan Liquified Natural Gas Company Ltd. Capacity: 4,7 million t/y each
EPC in JV
• Dukhan Field Gas Lift Location: DukhanClient: Qatar Petroleum (QP) Capacity: to maintain a production of 440,000 b/d
LSTK
• Al-Khaleej Gas Project Location: Ras LaffanClient: ExxonMobilCapacity: 750 MMSCFD
EPC in JV
Snamprogetti 77
Major Projects Completed in 2001/2004 (1)
EPC• Natural Gas Treatment ComplexLocation: AsabClient: ADNOC Capacity: 856 million SCFD
ABU DHABIABU DHABI
•IGCC PlantLocation: SarrochClient: SarluxCapacity: 550 MWe
LSTK
ITALYITALY
The world’s largest IGCC plant
• Blue Stream Project Client: Saipem/Bouygues ConsortiumTotal length: 385 km (2 x 24”) Maximum depth: 2,150 m
Engineering Services
RUSSIA RUSSIA -- TURKEYTURKEY
Snamprogetti 88
WORLDWIDE REFERENCES WORLDWIDE REFERENCES RESIDUE HYDROCONVERSION UNITSRESIDUE HYDROCONVERSION UNITS
PEMEXCapacity : 50,000 BPSD
Licensor : IFPNATechnology : E.B.
Inv. Cost : 600 MUS$Scope of Work : T.K.L.S.
Start Up : 1997
PKN ORLEN S.A.Capacity : 34,000 BPSD
Licensor : IFPNATechnology : E.B.
Inv. Cost : 130 MUS$Scope of Work : Eng.& Mat. Supply
Start Up : 1999
AGIP Petroli Taranto Ref.Capacity : 14,000 BPSD
Licensor : SHELLTechnology : F.B.
Inv. Cost : 160 MUS$Scope of Work : T.K.L.S.
Start Up : 1994
Raffineria MediterraneaCapacity : 25,000 BPSD
Licensor : ABB LUMMUS GLOBALTechnology : E.B.
Scope of Work : Eng. ServicesStart Up : 1997
HEAVY RESIDUE HYDROCONVERSION UNIT
Snamprogetti 99
HYDROCONVERSION UNITS REACTORS VIEWREFERENCE “A”
Snamprogetti 1010
REFERENCE “B”
HYDROCONVERSION UNITS MODEL VIEWREACTORS & CATALYST HANDLING
Snamprogetti 1111
REFERENCE “C”
HYDROCONVERSION UNITSREACTORS LIFTING
Snamprogetti 1212
REFERENCE “D”
HYDROCONVERSION UNITSREACTORS VIEW
Snamprogetti 1313
REFERENCE “D”H-OIL UNIT VIEW
Snamprogetti 1414
HYDROCRACKING UNIT
RAFINERIA GDANSKA S.A. Capacity: 28,000 BPSD
Licensor: CHEVRONContract: EMSStart Up: 1999
SLOVNAFTCapacity: 16,960 BPSD
Licensor: UNOCALContract: LS
Start Up: 1990
PKN ORLENCapacity: 53,000 / 68,000 BPSD
Licensor: UOPContract: EMS
Start Up: 1997 / 2003AGIP PETROLI
Capacity: 35,000 BPSDLicensor: UNOCAL
Contract: TKLSStart Up: 1992
SARASCapacity: 100,000 BPSD
Licensor: SHELLContract: LS / REIMB.
Start Up: 1991
TUPRASCapacity: 17,250 BPSD
Licensor: UOPContract: TKLSStart Up: 1993
TUPRASCapacity: 23,000 BPSD
Licensor: UNOCALContract: TKLSStart Up: 1997
AGIP PETROLICapacity: 35,000 BPSD
Licensor: UNOCALContract: TKLSStart Up: 1994
ENERGOINVESTCapacity: 7,700 BPSD
Licensor: UOPContract: LS
Start Up: 1971
NIOCCapacity: 9,280 BPSD
Licensor: UOPContract: TKLSStart Up: 1973
NIOCCapacity: 18,000 BPSD
Licensor: UOPContract: TKLSStart Up: 1977
NIOCCapacity: 28,000 BPSD
Licensor: UOPContract: LS / REIMB
Start Up: 1998
SCOPCapacity: 38,000 BPSD
Licensor: UOPContract: LS / REIMB.
Start Up: 1981
KNPCCapacity: 23,000 BPSD
Licensor: UOPContract: LS
Start Up: 1975 ADNOCCapacity: 27,000 BPSD
Licensor: UOPContract: LS / REIMB.
Start Up: 1985
WORLDWIDE REFERENCES HYDROCRACKING UNITSWORLDWIDE REFERENCES HYDROCRACKING UNITS
Snamprogetti 1515
Snamprogetti 1616
““EST”EST”Eni Slurry TechnologyEni Slurry Technology
R & D ACTIVITIES
Catalyst Screening and Evaluation of Catalyst Screening and Evaluation of
Best Process OptionBest Process Option from 1988 to 1995from 1988 to 1995
Laboratory Laboratory MicroreactorMicroreactor TestsTests 19961996
Bench Scale TestsBench Scale Tests from 1997 to 1998from 1997 to 1998
Pilot Plant Eng./Pilot Plant Eng./ConstrConstr.. from 1998 to 1999from 1998 to 1999
Pilot Plant TestsPilot Plant Tests from May 1999from May 1999
Snamprogetti 1717
EST Technology Main Features
StabilityStability limitlimit PhasePhase separationseparation
AsphaltenesAsphaltenes
MaltenesMaltenes
Asphaltenes recycle + catalystThe EST approach
Time Course of Reaction
Snamprogetti 1818
Vacuum
Residue
Catalyst Make-up
SlurryReactor
Hydrogen
Asphaltene / Catalyst Recycle Purge
S.D.A.
Solvent (C3 or C4)
DAOConv. Unit
Feed
Fractionator
GAS + LPG+ H2S
Naphtha
Gasoil
VGO
EST Flow Diagram
Snamprogetti 1919
R & D and ENGINEERING ACTIVITIES
From May 1999 to presentFrom May 1999 to present
Pilot Plant TestsPilot Plant Tests on various feedstockon various feedstock
Fluid Dynamic StudyFluid Dynamic Study
Erosion / Corrosion TestsErosion / Corrosion Tests
Process and Detailed Engineering Design of Process and Detailed Engineering Design of Commercial Demonstration Plant (CDP)Commercial Demonstration Plant (CDP)
Product Reactivity TestsProduct Reactivity Tests
Snamprogetti 2020
Snamprogetti 2121
The EST Pilot Plant
« In operation since 1999
« Capacity 0.3 bbl/d
« Several feedstocks processed
« Continuous recycle operation
« No evidence of coke formation
FEEDSTOCK & PRODUCTS
Snamprogetti 2222
No Coke
GasoilNaphtha DAO
Characteristics of Different FeedstocksProcessed in the 0.3 bbl/d Pilot Plant
Feedstock Properties Ural ArabianHeavy
Zuata Maya Athabasca
Specific gravity (g/cm3) 1.0043 1.0312 1.029 1.0643 1.0147
°API gravity 9.4 5.7 6.0 1.5 8.0
500°C+ content (wt%) 91 96 95 99 60
H/C 1.494 1.366 1.349 1.333 1.42
Sulphur (wt%) 2.60 5.28 4.24 5.24 4.58
Nitrogen (wt%) 0.69 0.45 0.97 0.81 0.48
Ni and V (ppm) 74 / 242 52 / 170 154 / 697 132 / 866 70 / 186
n-C7 Asphaltenes (wt%) 10.5 19.5 19.7 30.3 12.4
CCR (wt%) 18.9 22.9 22.1 29.3 13.6
Snamprogetti 2323
Comparative Performance of Different Feedstocks in the 0.3 bbl/d Pilot Plant
Product yields (wt%) Ural ArabianHeavy
Zuata Maya Athabasca
Gas (HC+H2S) 11.5 10.9 15.1 9.9 12.9Naphtha (C5-170°C) 5.8 4.9 14.0 3.9 4.1Gasoil (170-350°C) 32.5 30.6 39.1 26.9 39.1Vacuum Gasoil (350-500°C) 29.8 29.2 23.3 34.9 32.1DAO (500°C+) 20.4 24.4 8.5 24.4 11.8
Upgrading performance% HDS 86 82 86 84 83% HDM > 99 > 99 > 99 > 99 > 99% HDN 54 41 59 52 47% CCR reduction 97 97 98 96 95% Conversion > 99 > 99 > 99 > 99 > 99
Snamprogetti 2424
Comparison Comparison CrudesCrudes vsvs ESTEST
-27
-48-64 -62.5
5.5 11.8 7.6 5.3
23
31
16.33
33
20
40.5
21
35.6
32
41
22.17
35
9
34.1
15
39.516.8
18.2
12.45
14.4
7
9.6 9.2
0.6 1.8 3.1 2.1
0.51
1.05
1.2
3.7 8.35.14
-70%
-60%
-50%
-40%
-30%
-20%
-10%
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Ural Ural EST Maya Maya EST Athabasca Athabasca EST Zuata Zuata EST
Case
wt.
%
Vac Res DAO 350÷500 170÷350 C5÷170 C1÷C4 H2S
°API 31,7 S 1,6 wt.% N 0,2 wt.% CCR 4,3 wt.% Ni/V 15/51 wppm
°API 21,5 S 3,4 wt.% N 0,4 wt.% CCR 10,8 wt.% Ni/V 53/277 wppm
°API 8,1 S 4,5 wt.% N 0,4 wt.% CCR 13,1 wt.% Ni/V 72/194 wppm
°API 8,6 S 3,8 wt.% N 0,66 wt.% CCR 14,5 wt.% Ni/V 88/411 wppm
°API 28,4 S 1,4 wt.% N 0,2 wt.% CCR 0,5 wt.% Ni/V < 1 wppm
°API 35,7 S 0,9 wt.% N 0,08 wt.% CCR 0,2 wt.% Ni/V < 1 wppm
°API 23,4 S 1,8 wt.% N 0,2 wt.% CCR 0,6 wt.% Ni/V < 1 wppm
°API 29,7 S 1,3 wt.% N 0,2 wt.% CCR 0,6 wt.% Ni/V < 1 wppm
Snamprogetti 2525
Yields Comparison
-64
7.620
40.5 49.6 44.29
34.122.6 28.4
7
9.6
9.1 11.3
3.1
1.6
-10.7-14.5
3.8
5.1
2.12.1
-70%
-60%
-50%
-40%
-30%
-20%
-10%
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Athabasca Athabasca EST Athabasca EB+ Naphtha & GasoilHDT
Athabasca DC + Naphtha & GasoilHDT + HCGO HDC
Case
wt.
%
Vac Res/Fuel Oil/Coke DAO Cat Feed Gasoil Naphtha LPG + Gas H2S
°API 8,1 S 4,5 wt.% N 0,4 wt.% CCR 13,1 wt.% Ni/V 72/194 wppm
°API 23,4 S 1,8 wt.% N 0,2 wt.% CCR 0,6 wt.% Ni/V < 1 wppmYield 100 wt.%
°API 21,4 S 1,6 wt.% N 0,2 wt.%CCR 0,8 wt. % Ni/V 44 wppmYield 100 wt.%
°API 25,7 S 1,6 wt.% N 0,2 wt.%Liquid Product Yield = 89,3 wt.%Li id P d t
Snamprogetti 2626
Snamprogetti 2727
EST CDP View
Estimated Production from Top 9 Countries for 2003 and 2015
9817
8543
7454
3852 3789
3396 3260 2987 2986
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
KB
bl /
d
Saudi Arabia Russia UnitedStates
Iran Mexico China Norway Venezuela Canada
1 2 3 4 5 6 7 8 9
2003
Source: BP World Oil Review, NEB and Lehman Brothers estimates
Snamprogetti 2828
Estimated Production from Top 9 Countries for 2003 and 2015
8639
7515
6560
5028
3390 33342988 2869
2629
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
KB
bl /
d
Saudi Arabia Russia UnitedStates
Canada Iran Mexico China Norway Venezuela
1 2 3 4 5 6 7 8 9
2015
Source: BP World Oil Review, NEB and Lehman Brothers estimates
Snamprogetti 2929
Snamprogetti 3030
STUDY OBJECTIVE & APPROACH
To provide updated economics of application of EST technology for the upgrading of Athabasca Oil Sands Bitumen in comparison with other competing upgrading technologies
The merit of implementing an Upgrading Complex based on these technologies has been investigated by conducting a Cash Flow Analysis and by calculating the inherent profitability indexes
Cash Flow projections have been carried out in current US$ (2.5%/y) and unlevered terms (100% Equity Funding)
Snamprogetti 3131
CRUDE OIL & NATURAL GAS PRICING
Athabasca crude oil (8.1 °API, 4.52 wt.%S) has been valued at 14.7 US$/bbl (year 2010) on the basis of °API value and Sulphur content
Natural gas cost has been taken at 2.9 US$/MBtu(year 2010) at plant battery limits
“TREND 2010”: Refers to a scenario for year 2010 and onwards. Brent crude oil is set at 25 US$/bbl (fob) in year 2010, corresponding to 21.6 US$/bbl in year 2004
Snamprogetti 3232
STUDY CASES
AthabascaAthabasca Upgrading via EST (EST Case)Upgrading via EST (EST Case)
AthabascaAthabasca Upgrading via Upgrading via EbullatedEbullated Bed (EB Case)Bed (EB Case)
AthabascaAthabasca Upgrading via Delayed Coking (DC Case)Upgrading via Delayed Coking (DC Case)
Snamprogetti 3333
NAPHTHA(576 T/d)57.2 °API
S. G. = 0.750 S = 0.6 wppmN = 0.7 wppm
LIGHT GASOIL(4,784 T/d)34.6 °API
S. G. = 0.852S = 10 wppmN = 50 wppm
CONVERSION UNIT FEED
(9,799 T/d)14.6 °API
S. G. = 0.968S = 2.5 wt. %N = 2,777 wppmCCR = 1.19 wt. %
FUEL GAS (269 T/d)
FUEL OIL(123 T/d)
Visc. 50°C = 380 cStS = 1.12 wt. %
LPG (251 T/d)
SOLIDS(13 T/d)
DISTILLATIONS
HYDROGEN (Chemical)(233 T/d)
E S TUpgrading
Section
PURGETREATMENT
PACKAGE
SRGO 170÷350 °C
SR LVGO 370÷450 °CSR VGO 450÷540 °C
V.R. 540°C+ PURGE (84 T/d)
EST Case
LIQUID SULPHUR(483 T/d)
Crude Oil(16,114 T/d)
(100,000 BPSD)
S.G. = 1.0136 °API = 8.1 S = 4.52 wt.%N = 0.36 wt.%CCR = 13.12 wt.%Ni = 72 wppmV = 194 wppmNa = 32 wppm
Crude Oil(16,114 T/d)
(100,000 BPSD)
S.G. = 1.0136 °API = 8.1 S = 4.52 wt.%N = 0.36 wt.%CCR= 13.12 wt.%Ni = 72 wppmV = 194 wppmNa = 32 wppm
NAPHTHA(533 T/d)59.7 °API
S.G. = 0.740S = 0.5 wppmN = 1.0 wppm
FUEL GAS (411 T/d)
FUEL OIL(3,706 T/d)
5.9 °APIS.G. = 1.030S = 1.61 wt.%N = 0.573 wt.%Ni+V = 289 wppm
LPG (105 T/d)
DISTILLATIONS
Ebullated Bed
EB Case
SR HVGO
SR LVGO
HVGO
Snamprogetti 3434
V.R. 540°C+
HYDROGEN (Chemical)(195 T/d)
GASOIL(3,470 T/d)29.3 °API
S.G. = 0.880S = 10 wppmN = 21 wppm
CONVERSION UNIT FEED
(7,553 T/d)15.3 °API
S.G. = 0.964S = 2.53 wt%N = 0.17 wt%
LIQUID SULPHUR(474 T/d)
NaphthaHDT
LGOHDT
SRGO 170÷350 °C
HCGO HCK
NAPHTHA(1,097 T/d)58.2 °API
S. G. = 0.746S = 1 wppmN = 3 wppm
KEROSENE(334 T/d)34.2 °API
S. G. = 0.854S = 10 wppmN = 1 wppm
FUEL GAS (797 T/d)
COKE(2,727 T/d)
S = 6.82 wt.%N = 1.15 wt.%Ni+V = 1,458 wppm
LPG (158 T/d)
DISTILLATIONS
Delayed Coking
Snamprogetti 3535
V.R. 540 °C+
DC Case
SR HVGO
SR LVGO
HCGO
HYDROGEN (Chemical)(181 T/d)
GASOIL(4,597 T/d)27.5 °API
S. G. = 0.890S = 13 wppmN = 59 wppm
CONVERSION UNIT FEED
(6,184 T/d)16.0 °API
S. G. = 0.959S = 2.97 wt. %N = 0.15 wt. %
LIQUID SULPHUR(358 T/d)
NaphthaHDT
LGOHDT
Crude Oil(16,114 T/d)
(100,000 BPSD)
S.G. = 1.0136 °API = 8.1 S = 4.52 wt.%N = 0.36 wt.%CCR = 13.12 wt.%Ni = 72 wppmV = 194 wppmNa = 32 wppm
SRGO 170÷350 °C
Snamprogetti 3636
EX-PLANT PRODUCT PRICES(year 2010, current US$)
Product US$/tLPG 247 Naphtha 246 Jet/Kerosene 294 Diesel Oil (< 10 ppm wt S) 276 Conv. Unit Feed (> 2.5 wt.% S) 166 Fuel Oil (<1.0 wt.% S) 121 Sulphur 0 Coke 0
Snamprogetti 3737
FIXED INVESTMENT COSTS(year 2004 MUS$)
EST EB DCCase Case Case
Process Units (*) 914 917 844 Utilities & Offsites 176 180 205 Power Station 32 35 23 Storage 65 65 64 Export Facilities 10 10 10 Land 3 3 3 FACILITIES COST 1,200 1,210 1,149 Pre-operating Costs 36 30 29 FIXED INVESTMENT COST 1,236 1,240 1,178
(*) Includes royalties and initial catalysts charges
Snamprogetti 3838
ECONOMIC RESULTS
EST EB DCCase Case Case
IRR of Project Before Tax (%/y) 27.9 18.3 22.0IRR of Project After Tax (%/y) 20.9 13.9 16.6
NPV of Project After Tax (MUS$) 1,430 613 861(@ 8.1%/y, year 2004 values)
NPV/PV Capex 1.36 0.58 0.86(@ 8.1%/y)
Refinery Margin After Tax 5.3 1.1 2.0(@ 8.1%/y, year 2004 US$/bbl)
Snamprogetti 3939
UPGRADING MARGIN
Values in US$/bbl EST Case EB Case DC Case27.2 23.5 23.3
less:Opex 3.4 3.9 2.9of which gas 0.8 0.7 0.1Capex (@ 8.1%/y) 3.8 3.8 3.7
20.0 15.8 16.7less:
14.7 14.7 14.7
5.3 1.1 2.0UPGRADING MARGIN
Upgraded feed value
Net-back Crude Price
Base Crude Price
Snamprogetti 4040
ECONOMIC OUTCOMEThe EST economic benefits can be duly evaluated by the return on invested capital: up to 20.9%/y after tax and by the significant NPV close to 1.5 Billion US$ after tax for the “Trend 2010 Oil Scenario” (having considered a 8.1%/y remuneration of capital);
The outlined economic benefits are maintained for a wide range of investment and feedstock cost variation, and to a lesser extent also for the products value;
The sensitivity analysis to natural gas cost (i.e. hydrogen production) shows that EST remains attractive even for a major variation of its cost.
Snamprogetti 4141
SYSTEM BOUNDARIES
RefineryRefinery StepStep
Alternative CasesRefinery + Ebullated Bed on Vacuum Residue
Refinery + Delayed Coking on Vacuum Residue
Refinery + EST on Vacuum Residue
REFINERY+ EBULLATED BEDENERGY and MASS MACRO-BALANCES
Production
Middle Distillates = 3,887 kt/y
Refinery Balance Kt/y
INPUT Crude Oil 5,3715,580 Gas 209
OUTPUT Middle Distil. 3,887 5,580 Fuel Oil 1148
Sulphur 158Internal Fuels 225 Losses & adj 162
REFINERY
Distillates3,887 kt
Losses & Adj162 kt
Sulphur158 kt
Internal Fuels225 kt
5,371 kt
Fuel Oil 1,148 kt
EbullatedBedVacuum Residue
2802 kt
Catalysts
279 GWh
Natural Gas
231 Kt
Athabasca Bitumen
Combined CycleNat. gas eff. 53%
40 Kt
209 Kt
22 Kt UTILITY PRODUCTION
AdditionalElectric Power
Snamprogetti 4242
REFINERY + DELAYED COKING ENERGY and MASS MACRO-BALANCES
Production
Middle Distillates = 4,077 kt/y
Refinery Balance Kt/y
INPUT Crude Oil 5,371
5,541 Gas 170
OUTPUT Middle Distil. 4,077
5,541 Coke 899
Sulphur 118
Intern. Fuels 263
Losses & Adj 184
REFINERYDistillates4,077 kt
Internal Fuels263 kt
Losses & Adj184 kt
Sulphur118 kt
5,371 kt
Coke 899 kt
DelayedCokingVacuum Residue
2802 kt
Catalysts
175 GWh
Natural Gas
150 Kt
Athabasca Bitumen
Combined CycleNat. gas eff. 53%
26 Kt
UTILITY PRODUCTION
20 Kt
170 Kt
243 Kt
AdditionalElectric Power
Snamprogetti 4343
REFINERY + EST ENERGY and MASS MACRO-BALANCES
Production
Middle Distillates = 5,063 kt/y
Refinery Balance Kt/y
INPUT Crude Oil 5,371 5,590 Gas 219 OUTPUT Middle Distil. 5,063 5,590 Sulphur 159
Internal Fuels 129 Losses & adj 239
REFINERYDistillates5,063 kt
Internal Fuels129 kt
Sulphur159 kt
5,371 ktEST
Vacuum Residue2802 kt
Catalysts
247 GWh
Natural Gas
413 Kt
Athabasca Bitumen
Combined CycleNat. gas eff. 53%
36 Kt
219 Kt
194 KtUTILITY PRODUCTION
AdditionalElectric Power
Losses & Adj239 kt
Snamprogetti 4444
DISTILLATES PRODUCTION & CRUDE OIL SUMMARYNon Conventional Crude - Canada
Eb. Bed Coking ESTKt/y Kt/y Kt/y
GPL 35 52 83Naphtha 178 362 189Gasoline 98 RON 0 0 0Gasoline 95 RON 0 0 0Naphtha + Gasoline 178 362 189Jet + Kero 0 110 0Gasoil 1157 1515 1572Conversion Unit Feed 2518 2038 3220Total Gasoil 3675 3553 4792
TOTAL DISTILLATES 3888 4077 5064Pet-Coke 0 900 0
Fuel Oil 1123 0 41
CRUDE OIL 5371 5371 5371
Snamprogetti 4545
Snamprogetti 4646
DISTILLATES YIELDS
Refinery distillates yields (kg Dist/kg Crude) • 100
♦ Upgrading Option Gateout/Gatein
♦ Ebullated Bed 72.4 %
♦ Delayed Coking 75.9 %
♦ EST 94.3 %
LCA EST Technology – Non-Conventional CrudeUpstream Case - Canada
CO2 Emissions - Gate to Gatekg CO2/ton Dist
0500
100015002000250030003500400045005000
RR + Ebullated Bed (EB) RR + Delayed Coking (DC) RR + EST
kg C
O2/to
n Di
st
Refinery Byproducts Distillates Total
Snamprogetti 4747
LCA EST Technology – Non-Conventional CrudeUpstream Case - Canada
SO2 Emissions - Gate to GateKg SO2/ton Dist
0
10
20
30
40
50
60
70
RR + Ebullated Bed (EB) RR + Delayed Coking (DC) RR + EST
Kg S
O2/
ton
Dist
Refinery Byproducts Distillates Total
Snamprogetti 4848
LCA EST Technology – Crude Comparison
Conservative Estimate to include Up-grading
Crude Oil Upgrading - CO2 EmissionsKg CO2/ton Dist
0
1000
2000
3000
4000
5000
6000
EB DC EST EB DC EST
Kg C
O2/
ton
Dis
UpgradingDistil la te sByproductsRe fine ry
Heavy Crude (8,1 °API) Light Crude (34 °API)
API
21.5 API
24.7 API
22.9
API
50.4
API
49.9API
49.1
Conservative Estimate to include Up-grading
Crude Oil Upgrading - CO2 EmissionsKg CO2/ton Dist
0
1000
2000
3000
4000
5000
6000
EB DC EST EB DC EST
Kg C
O2/
ton
Dis
UpgradingDistil la te sByproductsRe fine ry
Heavy Crude (8,1 °API) Light Crude (34 °API)
API
21.5 API
24.7 API
22.9
API
50.4
API
49.9API
49.1
Snamprogetti 4949
Snamprogetti 5050
The EST Benefits
Total Feedstock Conversion
Outstanding Product Qualities
Total Metals Removal
No Fuel Oil or PetCoke Production
Low Catalyst Consumption
Excellent Feedstock Flexibility
Diesel Oil & Gasoline Meeting Future EU Specs
Snamprogetti 5151
EST : The Ultimate Solution for Resid Upgrading
Most Profitable Option
Higher Internal Rate of Return
Technologically Proven
Exploitation of Extra-HeavyCrude Oils
Bottom of the BarrelUpgrading
Exploitationof Oil Sands
Bitumen
Commercial Demonstration Plant on-stream within 2Q 2005
