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TRANSCRIPT
Bitumen Upgrader Residue Conversion to Incremental Synthetic Fuel Products
Organized by:
March 5-7, 2014 NEW ORLEANS, LOUISIANA, USA
HYATT REGENCY NEW ORLEANS
Steve Kresnyak, P.Eng
Jan Wagner, P.Eng
WHOC14-110 1
This presentation contains forward looking statements based on management’s assessments of future plans that involve engineering, operational and financial estimates of future production, capital expenditures, cash-flow and earnings. A number of risks and uncertainties that may or may not be within control of the company and may cause these results to vary materially from those predicated herein and the reader is therefore cautioned that such information is speculative in nature.
Legal Disclaimer
2
• Current State & Outlook Alberta Hydrocarbon Industry
• Introduction to FTCrude® Technology
• Review FTCrude® Process Configurations • FTCrude® Partial Upgrader to produce 20° to 24° API PUB
• FTCrude® Full Upgrader to produce 30° to 38° API Sweet SCO
• FTCrude® Refinery to produce ULSG, ULSD, ULSJ
• Basic FTCrude® Economics
• Summary – Why FTCrude®?
Introduction
3
Surplus of Natural Gas in North America – Alberta Gas not competitive in US markets - prices very low and Alberta Royalty recovery 30% of peak
Disconnect between North American NG Price and Oil Price
Alberta Oil Markets Restrained due to lack of Pipelines
Alberta Oil (Non–diluted Bitumen) discounted by 40% from WTI Price
Potential shortage of low cost Diluent to transport Alberta Bitumen
Alberta Oil (Bitumen) has no access to Foreign Markets and cannot enjoy favourable world “Brent” pricing
Alberta Oilsands Image low – “dirty oil”, high GHG emissions
Alberta at risk of NOT achieving GHG emission reduction goals for 2020
Current State of Alberta Hydrocarbon Industry
4
Long Term View of Energy Pricing?
5
Forecasted Growth of Alberta Oilsands
6
TCPL Energy East 850,000 BPD
Enbridge Northern Gateway 525,000 BPD
TCPL Keystone XL 830,000 BPD
Kinder Morgan Exp 590,000 BPD
Future Canadian Oilsands Production = 2,800,000 BPD
Proposed Solution to Alberta Oilsands Market
7
Outlook for Hydrocarbon Industry NG (AECO) Price expected to be less than $4.00 per GJ long term
World Oil price expected to be greater than $100 per BBL long term
Market pressure on Alberta Bitumen reducing value to less than $50
per BBL
Future high growth crude markets will be Asia; China, India
Production of Petcoke facing rising public opposition
Rising public pressure to reduce GHG emissions
Need for more efficient way to create value for 100% Alberta Oilsands Resources without diluent or Petcoke and produce highest quality transportation fuels and lowest GHG emissions to earn respect in world market!
8
Solutions for Alberta
Current Natural Gas Solutions Export gas to high value market – LNG Add value to Natural Gas – GTL, Methanol, DME, Ammonia
Build east/west oil pipelines to tidewater to gain access to new
global markets
Add value to Bitumen through partial or full upgrading - Dilbit does not add value
Add value to Bitumen using “cheap” natural gas
“Convert Bitumen Residues to incremental Synthetic liquids”
FTCrude® concept can offer the solution
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FTCrude® converts asphaltenes and other residues to synthetic fuels
Residues are gasified to produce syngas for subsequent Fischer-Tropsch (FT) catalytic conversion to produce incremental synthetic liquids
Natural gas is used in a parallel syngas generator to provide high hydrogen content syngas to satisfy required stoichiometric ratio for the FT synthesis
This syngas generator also provides hydrogen for the upgrading operation
10
11
FTCrude® Concept Schematic
ADU & DRU
H2
Syngas Treatment
Liquid Residue/Asphaltene
POX Gasifier Unit
H2
Recovery Unit
FT Reactor & Product Upgrading
SMR/ATRReformer
FTCrude®Island
Fuel Gas Treatment
SDA
VDUHydroprocessing
Unit
Diluent
Diluted Bitumen
Naphtha
Diesel
Gas-Oil
Refinery Fuel Gas(RFG)
Light Ends
AGO
VGO
DAO
Light Ends
Natural Gas,
LPG,RFG,
Naphtha, CO2
FT-Naphtha
SynDiesel®SynJet®
FT-LPG
CO2
Oxygen
LiquidSulfur
Fischer-Tropsch (FT) Process
•Natural Gas
•Biomass
•MSW
•Vacuum Residuals
•Asphaltene
•Petroleum Coke
Carbon
Source
POX
Gasifier
•Carbon Monoxide (CO)
•Hydrogen (H2)
•H2:CO = 2
Syngas
Production
•Catalytic conversion
•CO + H2 = Synthetic Hydrocarbon
•FT WAX
Fischer-Tropsch
Conversion
FT Product Upgrading
Zero sulfur, No aromatics, High cetane (70+) Synthetic Fuels
12
Conventional Crude Oil
20 to 40 API
12 to 20 API 6 to 12 API
Petcoke Solid Carbon
Carbon Content
Val
ue
in E
qu
ival
ent
Hea
t C
on
ten
t SynDiesel®
SynJet®
Hydrogen Content
Refinery Bottoms
Bitumen Heavy Oil Vacuum Bottoms Asphaltenes
Natural Gas LPG RFG Naphtha
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Maximum Retention of Carbon
Maximum Conversion of Carbon
Minimum Carbon Rejection – low GHG emissions, high carbon efficiency (90+%)
Maximum Conversion of low value carbon to high value transport fuels
Bitumen
Natural Gas
SynDiesel® SynJet®
FTCrude®
50% to 80% Reduction
100% 90+%
Petc
ok
e / R
esi
d
CO
2
Carbon Management Story
14
FTCrude® Life Cycle GHG Emissions (Jacobs Figure E-6 FTCrude® Process and credit for excess Power Credit added)
AERI-Jacobs LCA Report for North American & Imported Crudes – July 2009
CONVENTIONAL CRUDE OIL
CONVENTIONAL CRUDE OIL
15
Significant Benefits from Integration of GTL Plant with Heavy Oil & Bitumen Production
Typical GTL Plant = 1000 BBL FT Liquid/10 MMSCF Natural Gas FTCrude® = 2000 BBL FT Liquid/10 MMSCF Natural Gas & NO Petcoke
16
Integrated GTL Plant
Conventional Bitumen Upgrader or Refinery 60– 137,000 BOPD
Bitumen, Heavy Oil or Refinery Bottoms
High Value Sweet or Sour SCO or Refined Fuels
Synthetic Fuels
Natural Gas, LPG, RFG
30 – 300 MMSCFD
2000 – 30,000 BPD
50 – 100,000 BOPD
Oxygen
Wa
ter
Ste
am
Po
we
r
Op
tio
nal
BT
M B
BL
Hyd
rog
en
FTCrude® Additional Benefits
Process Water
Excess Power
17
FTCrude® Products and Application
All process units within the concept are proven technology and commercial licenses are available
Concept is patented & patent pending technology, licensed by Expander Energy Inc., Calgary, Alberta, Canada
The principal products are high value paraffinic naphtha and diesel/jet fuel
FTCrude® concept can be applied to wide range of applications including Partial and Full bitumen upgrading or bitumen refinery producing all light transportation fuels - gasoline, diesel/jet fuels
It can also be applied as a debottlenecking option to existing upgraders that use gasification of residues for hydrogen production
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0.5 to 1.2 MMSCF/KBBL SCO
Patent Issued & Pending
Conventional Upgrader •ADU/DRU •VDU •SDA •Amine/SRU, SWS
DILBIT
Sour SCO
• Resid Gasifier • FT Process • FT Upgrader • Syngas Generator
50,000 BPD Bitumen 21,500 BPD Diluent 8.5 API 4.5wt% S 17 wt% CCR
21,500 BPD Diluent
Natural Gas
Bit
um
en
Bo
tto
ms
Process CO2
Exce
ss L
PG
/ R
efin
ery
gas
FT L
iqu
ids
Ste
am/P
ow
er
Sulfur
Process Water
<20 Ton CO2/KBBL SCO
BOTTOMLESS PUB 54,500 BPD 20 to 24 API <3.3wt% S
109 vol% Yield
<300 cST @ 15 C <50 ppm metals
SG = 0.92 <4.0 wt% CCR
<1.0 TAN
Oxygen
FTCrude® Partial Upgrader
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Typical Bitumen Assay
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
AthabascaBitumenBlend
AthabascaBitumen
Pe
rce
nt O
f C
rud
e S
late
Crude Oils
Naphtha
Distillate
VGO
Vac Residue
21
3.7
38
20
3.5
>40
8.5
4.3
-
API
% Sulfur
Cetane
FTCrude®
PUB Asphaltene Liquid
concentrated in Sulfur & metals
VG
O
DA
O
Vac R
esid
ue
20
Patent Issued & Pending
Conventional Upgrader •ADU/DRU •VDU •SDA •Mild Hydrocracker •Hydrotreater •Amine/SRU, SWS
DILBIT
Sweet SCO
• Resid Gasifier • FT Process • FT Upgrader • Syngas Generator
50,000 BPD Bitumen 21,500 BPD Diluent
21,500 BPD Diluent
Natural Gas
1.0 to 1.6 MMSCF/KBBL SCO
60,500 BPD 30 to 40 API <1000 ppm S 121 vol% Yield
Bit
um
en
Bo
tto
ms
Process CO2
Exce
ss L
PG
/ R
efin
ery
gas
FT L
iqu
ids
Ste
am/P
ow
er
Sulfur
Process Water
<20 Ton CO2/KBBL SCO
Hyd
roge
n
Optional SynDiesel® & SynJet®
Oxygen
FTCrude® Full Upgrader
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0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
AthabascaBitumen
Blend
AthabascaBitumen
Perc
en
t O
f C
rud
e S
late
Crude Oils
Naphtha
Distillate
VGO
Vac Residue
21
3.7
38
>34 <0.09 >40
8.5
4.3
-
API % Sulfur Cetane
FTCrude®
SCO
Hydro
Cracker
Asphaltene Liquid concentrated in Sulfur & metals
VG
O
DA
O
Vac R
esid
ue
Typical Bitumen Assay
22
High Product Yield
137% vol yield
68,500 BPD
Patent Issued & Pending
Conventional Refinery •ADU/DRU
•VDU
•SDA
•Full VGO Hydrocracker
•Gasoline Reformer /FCC
•Hydrotreater(s)
•SWS, Amine/SRU
DILBIT
ULSJ Jet Fuel
• Resid Gasifier
• FT Process
• FT Upgrader
• Syngas Generator
50,000 BPD Bitumen
21,500 BPD Diluent
21,500 BPD Diluent
Natural Gas
2 to 2.6 MMSCF/KBBL SCO
Ma
xim
um
Bit
um
en
Bo
tto
ms
Process CO2
Ex
ce
ss
LP
G/
Re
fin
ery
gas
FT
Liq
uid
s
Ste
am
/Po
wer
Sulfur
Process Water
<20 Ton CO2/KBBL SCO
Hyd
rog
en
ULSD Diesel
ULSG Gasoline
Oxygen
FTCrude® Refinery
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Typical Crude Assays
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
WTI AlaskaNorthSlope
ArabianMedium
AthabascaBitumenBlend
AthabascaBitumen
CanadianSweetSCO
FTCrudePUB
FTCrude®SCO (min)
FTCrude®SCO (max)
FTCrude®Refinery
Pe
rce
nt
Of
Cru
de
Sla
te
Crude Oils
Naphtha
Distillate
VGO
Vac Residue
39.6 0.49 45
30.
3
2.5
32 0.9 38
21
3.5
>50
8.0 4.3 -
21 3.7 38
API % Sulfur Cetane
32.2
0.16
35
>35
<0.09
>50
>35
<0.09
>50
>50
<0.00
>50
24
FTCrude® Economic Feasibility Chart
0
5
10
15
20
25
30
50 60 70 80 90 100 110 120 130
Rat
e o
f R
etu
rn (
%)
WTI ($CDN/BBL)
NG-$3/GJ
NG-$6/GJ
NG-$12/GJ
Natural Gas
25
FTCrude® Partial Upgrader Economics
CAPEX for 50,000 BPD FTCrude® Partial Upgrader
= $1,600 M total over 2 years
Revenues
• FTCrude® PUB Sales 54,500 BPD X $75/BBL X 347 day/yr = $1,418 M/yr
Estimated Operating Cost
• Bitumen Feed Cost 50,000 BPD X $50/BBL X 347 day/yr = $ 868 M/yr
• Oxygen Supply 1050 TPD X $50/Tonne X 347 day/yr = $ 18 M/yr
• Natural Gas Requirement 60 MMSCFD X $4/MSCF X 347 day/yr = $ 83 M/yr
• Additional Fixed Opex 4% X Capex = $ 64 M/yr
Net BT Revenue = $ 385 M/yr
Est BT IRR = 22% Est NPV@15% = $703 M 1 PUB
Value= $WCS +$5= $75 per BBL Note 2: Cost of Diluent Use – Cost Recovery = $
Note 1: PUB Value = $WCS + $5 = $75 /BBL
Note 2: Cost of Diluent Use = Cost Diluent + Handling – Cost Recovery = $20 / BBL Bitumen
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Est Capex for 50,000 BPD FTCrude® Refinery
= $4,600 M total over 2 years Revenues
• FTCrude® Synfuel Sales 68,500 BPD X $120/BBL X 347 day/yr = $ 2,852 M/yr
Estimated Operating Cost
• Bitumen Feed Cost 50,000 BPD X $50/BBL X 347 day/yr = $ 868 M/yr
• Oxygen Supply 1850 TPD X $50/Tonne X 347 day/yr = $ 32 M/yr
• Natural Gas Requirement 143 MMSCFD X $4/MSCF X 347 day/yr = $ 198 M/yr
• Additional Fixed Opex 4% X Capex = $ 180 M/yr
Net BT Revenue = $1,574 M/yr
Est BT IRR = 30% Est NPV@15% = $4,687 M
Note 1: Cost of Diluent Use = Cost Diluent + Handling – Cost Recovery = $20/BBL Bitumen
FTCrude® Refinery Economics
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Summary - Why FTCrude®? All process units are proven technology and commercial licenses
available – low technical risk
100% conversion of Alberta Bitumen to high value transportation fuels
Greater than 120% volume yield of refined products to bitumen supply
Greater than 50% GHG emission reduction through high carbon retention/conversion by the system
Concept is economically robust for a wide range of natural gas and crude oil prices (gas as high as $12/mmbtu)
Concept will benefit from long term pricing -natural gas (<$5/mmbtu) and high crude oil prices (~$100/bbl)
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QUESTIONS? Steve Kresnyak, P.Eng Chief Technology Officer Expander Energy Inc. [email protected] (403)-819-4211 Jan Wagner, P.Eng Chief Process Engineer Expander Energy Inc. [email protected] (403)-472-1280
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Thank you
Bitumen Upgrader Residue Conversion to Incremental Synthetic Fuel Products
Steve Kresnyak, P.Eng
Jan Wagner, P.Eng
WHOC14-110 30