renewable feeds co-processing using existing heavy ends
TRANSCRIPT
BBTCRenewable Feeds Co-processing
Using Existing Heavy Ends
Refinery Platform
Thursday, 30th September, 2021
■ Co-processing in fossil fuel refineries made up about 10% of total HVO production in
2019
■ Biofuel production from co-processing should triple by 2025 (~1.4 billion litres in 2025 vs.
0.5 in 2018)
■ Co-processing will be mainly implemented in Europe
Outlook to 2030: The Role of Co-processing
Source : IEA, 2020
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Renewable Feedstock Outlook
Type Feedstock Supply Demand Future Outlook
Refined oils
Palm Oil
Soybean Oil
Rapeseed Oil
Sunflower Oil…
Represent only a fraction of
total global production
Legislation not in favor of
crop-based bio feeds
Mid-term availability
guaranteed
Waste oils & fats
UCO
Tall oil
Tallow – Animal fat
POME
Limited additional supply
Already high collection rates
Support from legislation
Premium benefits
Highly constrained to existing
supplies
Py Oil (Fast pyrolisis)
&
Bio crude(Hydrothermal
liquefaction)
Converted:
Agricultural residue
Forestry residue
Algae
Sewage sludge
MSW
Pneumatic tires
Collection circuit to be built.
Variability in py-oil / bio
crude feedstock quality.
High potential from new
emerging feedstock
Technology / Legislation not
fully mature
High interest and support
from pioneering companies
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Axens’ History with Biofuels / Co-processing
1992
2006
1st biodiesel plant
start-up
Esterfip™ Technology
1st Esterfip™-H
plant
start-up
1st Industrial reference of Vegan®
Total La MèdeBiorefinery Project
2015 1st grass root
PrimeD®
Co-Processing Design
2018
2010
1st Co-processing
industrial reference
in a DHT unit
2014
2020
2021
Co-processing
Pilot tests on
H-Oil unit
1st Co-processing
trials in an FCC unit
Co-processing
lipids Pilot test on
FCC unit
Co-processing FPO
Pilot test on FCC
unit
2007
Co-processing paths
Refined Oils
Waste Oils & Fats
Renewable
Fuels
AromaticsPy Oil & Bio crude
Bio
Petrochemicals
feedstocks
Prime D ®
+ HyK ™
H-Oil ®
FCC
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Co-Processing Renewable feedstock in
Hydroprocessing units
Lipids Hydrotreatment – Reactions Scheme
H2-C-OO-C
H-C-OO-C
H2-C-OH
H2-C-OO-C
H-C-OH
H2-C-OH
H2-C-OO-C
H-C-OO-C
H2-C-OO-C
HOO-C
Hydrogenolysis
TG + 12 H2 3 C18H38 + 6 H2O + C3H8
1
2 Decarboxylation
TG + 3 H2 3 C17H36 + C3H8 + 3 CO2
H2
/ Hydrogenation
/ Hydrogenation
Methanation / WGS
CO2 + 4 H2 CH4 + 2 H2O
CO2 + H2 ↔ CO + H2O
3
Free Fatty Acids
Monoglycerides
Diglycerides
Triglycerides (TG)
Renewable
Oils & Fats:
1 2
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Light
Ends
M/U H2
Off-gas
H2 Recycle
∞
ULSD
Feed
Wild Naphtha
Exotherm
Undesirable Impact
Desirable Impact
Bio-feed
Increased
corrosion
Impact on
Catalyst
Activity
H2 purity
CO/CO2 build-up
Cetane
Density
CFP
H2
consumption
Risk of
fouling
Increased
corrosion
Case Study: Impact of Co-Processing on DHT Units
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Reactor Inlet Internals
■ Filtering Tray – Hy-Clean™
Smart filtering tray system for
services prone to fouling and/or ΔP
Installed above the dist. tray without
relocation
Do not require any connection to
reactor wall
Baskets typically filled with grading
By-passable| 9
Smart DP Management
0
1
2
3
4
5
6
7
8
0
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
0 200 400 600 800 1000 1200 1400
Pre
ss
ure
dro
p b
ar
VO
vo
l%
Days on stream
Reactor Pressure Drop
VO vol% DP Norm. dp 1 Norm. dp 2 Norm. dp 3 Norm. dp 4 max DP
Skimming
H2 Stripping
Skimming
FeS dispersant injection at reactor inlet
Customer GALP
3700 mm Refinery Sines
Unit name HD
Reactor Id. HD-V-1
TL 320 mm
ActiPhase 3D TRANS 30 80 mm 0.860 m3CatTrap 30 130 mm 1.398 m3
CatTrap 50 170 mm 1.828 m3
CatTrap 65 170 mm 1.828 m3
ACT 077 (11 mm) 160 mm 1.720 m3
ACT 935 (6.2 mm) 190 mm 2.043 m3 1.073 tons
ACT 955 (2.5 mm) 230 mm 2.473 m3 1.607 tons
ACT 971 (2.5 mm) 230 mm 2.473 m3 1.410 tons
HR 538 (1.6 mm) 210 mm 2.258 m3 1.445 tons
HR 648 (1.6 mm) 80 mm 0.860 m3 0.628 tons
Dense Reg HR 538 (1.6 mm) 2340 mm 25.160 m3 18.618 tons
Dense HR 1218 (1.6 mm) 12340 mm 132.681 m3 108.135 tons
TL HR 1218 (1.6 mm) 840 mm 8.411 m3 6.855 tons
Inert Balls (1/4 inch.) 150 mm 1.217 m3 1.704 tons
Inert Balls (3/4 inch.) 504 mm 3.268 m3 4.412 tons
Note 1: This drawing gives a description of the proposed loading diagram, nevertheless the scale is not proportional.
Note 2: Inert Balls volume in the reactor bottom to be confirmed with actual reactor scheme
Note 3: Inert Balls (3/4 inch.) to be loaded at least 100 mm above bottom screen
Note 4: Indicated weights are under oxyde form before Impulse™ treatment
Grading solutions
Period 1 Period 2 Period 3 Period 4
6 months 7 months 9 months17 months
on-going
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Co-Processing Renewable feedstock in FCC units
■ Owing to decreased demand in motor fuels, some
FCCUs are currently operating below their nameplate
capacities, allowing for co-processing bio feeds.
■ Fluid Catalytic Cracking process has the capability to:
Deal with heavy and polluted feeds
Can adapt to various grades/qualities of bio-oils
No systematic need for pre-treatment
Accomodate to feed capacity or yield pattern changes
Will absorb seasonal variations in bio-oil feed quality and
quantity
Will allow switching bio-feed sources
Generate various products from motor fuels to petchem bases
FCCUs as co-processing machines
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■ Careful handling of bio-oil material (polymerization, etc.)
Specifically designed injectors available
Independant lines, when necessary, to control temperature
■ Operating conditions swings due to possibly inconsistent supply
Wide offer of flexible hardware capable to withstand transient phases and
operational swings:
› RS² riser termination device to avoid catalyst entrainments to fractionation section,
› Stripper Packing to avoid hydrocarbons entrainments to regeneration section,
› etc.
■ Possible presence of noxious components
Very resilient process: most issues will be dealt with higher fresh catalyst make-
up rate
Presence of heavy material inconsequential for R2R™ (Dual Regeneration FCC)
■ Corrosion
To be assessed on a case by case basis versus original design capability
Expected impacts with co-processing in FCCUs
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Expected performances: Cracking potential vs. VGO feed
PalmSoy-
bean
Rape-
seed
Sun-
flowerCorn
Jatro-
phaUCO
Animal
FatFFA TOFA
H2O+COx L L L L
Dry GasJJJ JJ JJJ J
EthyleneL L
LL LL
PropyleneK L L
LL
ButenesK L L
LL
GasolineJ J K J
SlurryJJJ JJ JJJ J
CokeJ J
LLJ
• Similar behaviour per
category
• Systematic reduced dry gas
and slurry production
• Performance impeded by
large production of H2O, CO,
CO2.
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INCREASED TREATMENT COMPLEXITY
■ Context:
Customer willing to leverage available overdesign margin in VGO FCCU
Potentially easy access to FPBO* material nearby
No unit modification besides new storage and injection facilities for FPBO
FPBO from spruce/pine, birch and, wheat straw feedstocks
■ Results
4% FPBO in 100% UCO+HCGO retained to comply with the above
Same operating conditions maintained with <1% drop in conversion
Fresh catalyst injection rate increased to deal with high Fe+Ca+Na contents
Distribution of bio-material in products:
Expected performances / Case Study
Dry gas 35%
LPG 5%
Gasoline 5%
LCO 20%
Slurry 35%| 14
* Fast Pyrolisis Bio Oil
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Co-Processing Renewable feedstock in EB units
■ H-Oil is the most suited technology for Residue
conversion application
Upflow Reactor, Recycle of Rx Liquid to ebullate catalyst
bed
Low and constant ΔP over the catalyst bed,
Nearly isothermal
High residue conversion: up to 95+% on Vacuum
Residue
No limitation on feed quality
■ On-line daily Addition/Withdrawal of catalyst:
Constant catalyst activity, whatever metal content in the
feed
Constant product quality
No Cycle length limitations
Fully automated system
H-Oil Platform specificitiesCatalyst Addition
Recycle Cup
Expanded
Catalyst Level
Settled
Catalyst Level
Hydrogen and
Feed Oil
Catalyst Withdrawal
Recycle Oil
Distributor
Grid Plate
Ebullated
Bed
Gas/Liquid
Separator
Possibility with EB to process « unrefined bio feeds »| 16
■ H-Oil operating conditions: High temperature (400-430°C),
High Pressure (160-180 bar)
Decarboxylation/ hydrogenation reactions
Conditions for complete Methanation
■ Bio-Feed qualities Metals and phospholipids – handle by CAR
› High silicium content but lower total metal than SRVR
Phospholipids - also prone to precipitate at 150-160°C. Selection of injection point
Nitrogen & Sulfur – dilution effect on VR
› Product qualities will be improved
■ Yields Increase Diesel range yield (+11%)*
Increase C3 formation (+8%)*
Small Increase on Hydrogen consumption (+4%)*
H-Oil Platform: a co-process VO machineCatalyst Addition
Recycle Cup
Expanded
Catalyst Level
Settled
Catalyst Level
Hydrogen and
Feed Oil
Catalyst Withdrawal
Recycle Oil
Distributor
Grid Plate
Ebullated
Bed
Gas/Liquid
Separator
* For 10% co-processing| 17
■ The reaction yields a lot of C3.
Potential impacts on membrane/PSA/gas plant and ppH2
■ CO and catalyst poisoning.
daily addition & withdrawal will help: should be check with spent catalyst
analysis.
■ High amount of unsaturated VO result in very high reaction exotherm
VO can be sent to 1st & 2nd reactors separately to reduce exothermicity risk
■ Chlorides content: corrosion potential
■ Check CO2 material balance with membrane supplier
VO up to 10% these challenges can be overcome easily
VO processing challenges:
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Selecting the optimum injection point
Type Characteristics
Refinery Injection Point
Hydroprocessing FCC H-Oil
Refined oils▼Level of FFA /
poisons
Specific grading
▲H2 Consumption
Loss of liquid yields
Subsequent treatment
Loss of liquid yields
Subsequent treatment
▲H2 Consumption
Waste oils & fats▲Level of FFA /
metals & poisons
Specific grading
▲H2 Consumption
Metallurgy upgrades /
Pretreatment
Loss of liquid yields
Subsequent treatment
▲Tolerance to polluted
feeds
Loss of liquid yields
Subsequent treatment
▲H2 Consumption
▲Tolerance to polluted
feeds
Py Oil (Fast pyrolisis)
&
Bio crude (Hydrothermal
liquefaction)
Unstable compounds
▲TAN / Chlorides
▲Oxygen/water level
Specific grading
▲O2 level
Pretreatment by
hydrogenation
Few experimental data
▲Tolerance to polluted
feeds
Separate injection point
▲Tolerance to polluted
feeds
▲H2 Consumption
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Multiple options for a « greener » futureNear-term solutions with no/minor modifications
Co-processing in existing refinery
units:
Simple, efficient and flexible
High potential to provide low carbon
renewable fuels at min CAPEX
Capturing premium « green » benefits
Maximum re-use of existing refining
infrastructure
Flexibility to respond to market fluctuations
Higher value products with High energy
content and improved cetane number
Our added value:
Continuous R&D on bio-fuels with
unique IFP pilot plant facilities
Revamp experience
+25 years of industrial feedback
Robust Catalyst
Internals portfolio
axens.net
Thank you