A PROCESS OF COPROCESSING A LIGNOCELLULOSIC LIQUID STREAM AND AN INTERMEDIATE FOSSIL STREAM IN AN OIL REFINING PROCESS AND A PROCESS FOR PRODUCING FUEL FROM A DEASPHALTED OIL STREAM

Description

FIELD OF THE INVENTION

The present invention relates to the coprocessing of a lignocellulosic liquid stream and an intermediate fossil stream in oil refineries.

Furthermore, the present invention relates to a process for producing fuels from a deasphalted oil stream comprising carbon of renewable origin.

BACKGROUND OF THE INVENTION

Mitigation of the problems resulting from the use of fossil fuels is being achieved by increasing the proportion of fuels of renewable origin in countries' energy matrix, stimulated by the public policy of incentivizing the use mainly of ethanol and biodiesel as more sustainable alternatives.

In recent years, sources of lignocellulosic material have opened up new possibilities for this scenario. It was found that lignocellulosic material, which hitherto was regarded as a process waste, can be used as a raw material for producing biofuels. In this way the economics of products of renewable origin is improved, adding value to the materials.

In this context, besides second-generation alcohol obtained, for example, by hydrolysis and fermentation of lignocellulosic material, thermochemical processes for converting lignocellulosic biomass are emerging as an interesting alternative for generating renewable streams.

Among the existing thermochemical processes for converting biomass, we may mention the processes of fast pyrolysis, slow pyrolysis (carbonization) and gasification. These processes are differentiated by the amount of oxygen available in the reaction mixture, residence time, reaction temperature and heating rate.

In particular, the process of fast pyrolysis of biomass stands out among the other processes for converting lignocellulosic material, since it gives higher yields in the generation of a liquid product.

The liquid product resulting from this process is called bio-oil or pyrolysis oil and has various oxygen-containing functional groups in its composition, resulting in an oxygen content in the range from 15 to 50%. However, this chemical characteristic results in undesirable properties that make it difficult to use bio-oil directly as a motor fuel, such as high acidity, low calorific value and chemical instability.

An alternative for using this pyrolysis oil with the aim of increasing the renewability of the energy matrixes is the combined processing of lignocellulosic biomass streams and fossil streams in existing units in oil refineries.

In this connection, some documents of the prior art describe the coprocessing of pyrolysis oil with intermediate streams from oil refining. These processes aim to overcome the problems associated with the resultant composition of the bio-oil, thus making it viable to use it as fuel.

The patent document CA 2819903 discloses a process for producing renewable biofuels based on the direct integration of a system for producing bio-oil and a conventional oil refinery, in which the renewable stream is coprocessed with the stream derived from petroleum.

This process includes the treatment of a mixed stream (bio-oil and fossil components) in a hydrofining unit, and then sending it to units for fluidized-bed catalytic cracking (FCC).

The document CA 2662059 describes a method for processing asphaltenes using a deasphalting solvent. After the deasphalting process, separate fractions are obtained of deasphalted oil and of asphaltene-rich oil. The asphaltene-rich stream can be mixed with a biomass stream with the aim of coprocessing the fossil stream with the renewable stream in a gasifier.

However, the direct use of bio-oil in refining processes has limitations relating to the percentage of bio-oil in the feed to be processed.

The main causes of these limitations are: (i) high value of carbon residue of the bio-oil, which may reach 30 wt % depending on the raw material and the conditions in which the pyrolysis is carried out; (ii) presence of alkali metals and alkaline earth metals in the liquids resulting from the conversion of lignocellulosic biomass, and (iii) formation of water, resulting in the dilution of valuable products.

In fluidized-bed catalytic cracking units (FCC), for example, the limitations as to the direct use of pyrolysis oil are mainly imposed by the increase in the yield of coke and by the rate of deactivation of the catalytic system during cracking.

Therefore the present invention aims to provide the coprocessing of a lignocellulosic liquid stream and a fossil stream in a deasphalting unit so as to overcome the limitations on feed to be introduced in conversion processes at oil refineries.

SUMMARY OF THE INVENTION

The present invention relates to the coprocessing of a lignocellulosic liquid stream and an intermediate fossil stream in the oil refining process.

The coprocessing described here comprises the following steps:

(a) contacting the intermediate fossil stream and said lignocellulosic liquid stream with a stream of solvent of C₃-C₁₀hydrocarbons in an extraction section, obtaining a stream of extract with solvent and a stream of raffinate with solvent; and

(b) sending the stream of extract with solvent to a separation section, obtaining a deasphalted oil stream comprising solvent-free carbon of renewable origin and a stream of recovered solvent.

The extraction section is a deasphalting unit of an oil refinery.

Moreover, the present invention also relates to a process for producing fuels from the deasphalted oil stream comprising carbon of renewable origin.

The process comprises sending the deasphalted oil stream to a conversion section of oil refineries.

The conversion section is selected from catalytic hydrocracking unit, hydrofining, thermal cracking, fluidized-bed catalytic cracking, visbreaking, delayed coking and catalytic reforming.

BRIEF DESCRIPTION OF THE FIGURES

The detailed description presented hereunder refers to the appended figures, where:

FIG. 1 shows a schematic flowchart of the coprocessing of a lignocellulosic liquid stream and an intermediate fossil stream in the oil refining process.

FIG. 2 shows a schematic flowchart of an embodiment of the coprocessing of a lignocellulosic liquid stream and an intermediate fossil stream in the oil refining process, with solvent recycling.

FIG. 3 shows a general flowchart of the process for producing fuels from a deasphalted oil stream comprising carbon of renewable origin in a conversion section.

FIG. 4 shows a schematic flowchart of the process for producing fuels from a deasphalted oil stream comprising carbon of renewable origin in an FCC unit.

DETAILED DESCRIPTION OF THE INVENTION

The present invention relates to a coprocessing of a lignocellulosic liquid stream and an intermediate fossil stream in the oil refining process.

The coprocessing claimed, as demonstrated in FIG. 1, comprises the following steps:

(a) contacting the intermediate fossil stream 1 and the lignocellulosic liquid stream 2 with a stream of solvent of C₃-C₁₀hydrocarbons 3 in an extraction section 9, obtaining a stream of extract with solvent 4 and a stream of raffinate with solvent 5, in which the extraction section is a deasphalting unit; and

(b) sending the stream of extract with solvent to a separation section, obtaining a deasphalted oil stream 6 comprising solvent-free carbon of renewable origin and a stream of recovered solvent 8.

FIG. 2 presents an embodiment in which the coprocessing comprises a step (c). Said step relates to the separation of the stream of raffinate with solvent 5 into a stream of recovered solvent 8 and a stream of asphaltic residue 7 in a separation section 11.

In addition, FIG. 2 shows an embodiment in which there is recirculation of the stream of recovered solvent 8 to the extraction section 9, the stream of recovered solvent being mixed with the solvent stream 3.

The coprocessing of the present invention preferably involves the use of a lignocellulosic liquid stream consisting of bio-oil and an intermediate fossil stream consisting of vacuum residue.

The preferred sources of natural raw materials for obtaining the lignocellulosic liquid stream include cellulose and hemicellulose obtained from leaves and bagasse, and sugars, such as sugar cane. In particular, the lignocellulosic liquid stream may come from the pulp and paper industry from the Kraft route.

In one embodiment of the invention, the hydrocarbon solvent employed in the coprocessing consists of C₃-C₇hydrocarbons, preferably resulting from oil refining processes. More preferably, the hydrocarbon solvent is selected from liquefied petroleum gas (LPG) and pentane.

The contacting of the solvent stream 3, in conditions without solvent recycling, or the contacting of the mixture of the solvent streams 3 and 8 with the combined feed consisting of streams 2 and 1 in the extraction section 9 takes place at a weight ratio between 0.5 and 10, preferably between 3 and 6.

The lignocellulosic liquid stream 2 corresponds to 0.1 to 99.9 wt % of the total feed added to the extraction section 9, preferably corresponding to 10 to 75 wt %.

In the context of the present invention, total feed added to the extraction section 9 means the feed consisting of the lignocellulosic liquid stream 2, intermediate fossil stream 1 and solvent stream 3, when there is no recycling of the stream of recovered solvent 8 to the extraction section 9 (FIG. 1).

When the recovered solvent 8 is recycled to the extraction section 9 (FIG. 2), total feed added to the extraction section 9 means the feed consisting of the lignocellulosic liquid stream 2, intermediate fossil stream 1 and the mixture of solvent streams 3 and 8.

The step of contacting the solvent stream 3 or the mixture of solvent streams 3 and 8 with the combined feed of streams 2 and 1 in the extraction section 9 takes place in the temperature range between 60° C. and 120° C. and in the pressure range between 100 and 10 000 kPa.

The present invention also relates to a process for producing fuels from the deasphalted oil stream 6 obtained in the claimed coprocessing.

The process, shown in FIG. 3, comprises sending the deasphalted oil stream 6 comprising carbon of renewable origin to an oil refinery conversion section 20. In section 20, the stream 6 is converted into the fuel stream 15′.

The conversion section 20 is selected from catalytic hydrocracking unit, HDT, thermal cracking, fluidized-bed catalytic cracking, visbreaking, delayed coking and catalytic reforming.

In one embodiment of the present invention, the deasphalted oil stream 6 is mixed with an intermediate fossil stream 12 before being sent to the conversion section in a proportion in the range from 30 to 70 wt %, based on the weight of the total feed fed into the conversion section 20.

In addition, the stream 6 may be mixed with the fossil stream 12 inside the conversion section 20, maintaining the proportion of the mixture in the range from 30 to 70 wt %, based on the weight of the total feed fed into the conversion section 20.

In a preferred embodiment, the conversion unit is a unit for fluidized-bed catalytic cracking (FCC).

The FCC unit, as demonstrated in FIG. 4, comprises a reaction section 20′, a rectification section 21 and a catalyst regeneration section 22.

The reaction section 20′ may operate in a temperature range between 400 and 700° C., preferably between 420° C. and 620° C., and has a residence time that varies between 1 and 10 seconds. There is also injection of steam between 5 and 50 wt %, based on the total feed fed into the reaction section.

FIG. 4 also shows that the product from the reaction section 20′ is a stream comprising a cracked effluent and a spent catalyst 14. The product is sent to the rectification section 21 for separating the cracked effluent 15 from the clean spent catalyst 16 and separation may be effected by cyclones in a preferred embodiment. The cracked effluent 15 may be gasoline, diesel or fuel oil.

The clean spent catalyst 16 is then sent to the catalyst regeneration section 22, and combustion gases 19 are generated after combustion of the catalyst with an air stream 18.

The regenerated catalyst 17 that leaves the catalyst regeneration 22 returns to the reaction section 20′.

The description given hereunder will be based on preferred embodiments of the invention. As will be obvious to a person skilled in the art, the invention is not limited to these particular embodiments.

EXAMPLES
Example 1—Process for Deasphalting Vacuum Residue with Pentane as Solvent

Vacuum residue, the characterization of which can be seen in Table 1, was deasphalted with pentane. The extraction temperature was maintained at 65° C. and the system was pressurized so that the solvent was in the liquid phase.

TABLE 1

Characterization of the vacuum residue.

Analysis
RV

Residue of Carbon by thermogravimetric
7.9%

analysis (RC-TG) (% w/w)

Elemental analysis (% w/w)

% N
1.0%

% C
86.7%

% H
11.4%

% S
1.1%

Index of Acidity (IAT) (mg KOH/g)
0.00

13C NMR carbonyl and carboxyl
<0.5%

13C NMR aromatics and olefinics
21.3%

13C NMR cyclooxygenated compounds
<0.5%

13C NMR ethers, esters and hydroxy
<0.5%

13C NMR alkyls
78.7%

The system was stirred for 6 hours, and was then submitted to separation of the two phases by decanting for 15 hours. The two fractions obtained were discharged from the system in the same condition of equilibrium proposed during the steps of extraction and decanting (phase separation). The results are presented in Table 2.

TABLE 2

Result of the deasphalting process of the

vacuum residue using pentane as solvent.

Results
100% RV

DEAO (deasphalted oil) [%]
87.8%

Elemental analysis (% w/w)

% N
0.8%

% C
86.2%

% H
11.9%

% S
0.3%

RC TG [%]
5.2%

IAT (mg KOH/g)
0.00

13C NMR carbonyl and carboxyl
<0.5%

13C NMR aromatics and olefinics
19.6%

13C NMR cyclooxygenated compounds
<0.5%

13C NMR ethers, esters and hydroxy
<0.5%

13C NMR alkyls
80.4%

Example 2—Coprocessinq of Vacuum Residue and a Lignocellulosic Liquid Stream A (BIO A) in a Deasphalting Process with Pentane as Solvent

The vacuum residue characterized in Table 1 was coprocessed with 10%, 25%, 33%, 63% and 75% by weight of the stream resulting from the conversion of lignocellulosic biomass A (BIO A) using pentane as solvent in the deasphalting process. The characterization of the stream BIO A is shown in Table 3. The weight ratio of pentane to the combined feed was equal to five.

The extraction temperature was maintained at 65° C. and the system was pressurized to 1379 kPa using molecular nitrogen. The system was stirred mechanically at 200 rpm for 6 hours, and was then submitted to separation of the two phases by decanting for 10 hours.

The two fractions obtained were discharged from the system in the same condition of equilibrium proposed during the steps of extraction and decanting. The results are presented in Table 4.

TABLE 3

Characterization of the stream BIO A.

Analysis
BIO A

RC TG [%]
16.1%

Elemental analysis (% w/w)

% N
0.3%

% C
42.6%

% H
7.3%

% S
0.3%

% O
49.5%

IAT (mg KOH/g)
96.1

13C NMR carbonyl and carboxyl
6.6%

13C NMR aromatics and olefinics
34.6%

13C NMR cyclooxygenated compounds
16.0%

13C NMR ethers, esters and hydroxy
19.5%

13C NMR alkyls
23.3%

TABLE 4

Result of the deasphalting process of the vacuum residue coprocessed

with the stream BIO A using pentane as soIvent.

Percentage of BIO A coprocessed

10%
25%
33%
63%
75%

DEAO [%]
83.8%
78.2%
71.1%
52.8%
43.3%

Elemental analysis (% w/w)

% N
1.0%
0.5%
0.7%
0.5%
0.5%

% C
85.8%
85.8%
85.4%
85.4%
84.2%

% H
11.6%
11.7%
11.7%
11.5%
11.3%

% S
0.6%
0.5%
0.5%
0.6%
0.5%

% O
1.0%
1.5%
1.6%
2.0%
3.5%

RC TG [%]
4.1%
3.9%
3.8%
3.5%
3.1%

IAT (mg KOH/g)
2.79
3.51
4.92
10.77
11.80

13C NMR carbonyl and
0.0%
0.5%
0.50%
0.80%
1.30%

carboxyl

13C NMR aromatic
21.0%
17.7%
21.4%
20.3%
20.9%

and olefinics

13C NMR
<0.5%
<0.5%
<0.5%
<0.5%
<0.5%

cyclooxygenated

compounds

13C NMR ethers,
0.0%
1.1%
1.2%
1.9%
2.1%

esters and

hydroxy

13C NMR alkyls
79.0%
80.3%
78.6%
79.7%
77.0%

Example 3—Coprocessing of Vacuum Residue and a Lignocellulosic Liquid Stream B (BIO B) in a Deasphalting Process with Pentane as Solvent

The vacuum residue characterized in Table I was coprocessed with 10%, 25%, 33%, 63% and 75% by weight of the stream resulting from the conversion of lignocellulosic biomass B (BIO B) using pentane as solvent in the deasphalting process. The characterization of the stream BIO B is shown in Table 5. The weight ratio of pentane to the combined feed was equal to five.

The two fractions obtained were discharged from the system in the same condition of equilibrium proposed during the steps of extraction and decanting. The results are presented in Table 6.

TABLE 5

Characterization of the stream BIO B.

Analysis
BIO B

RC TG [%]
21.3%

Elemental analysis (% w/w)

% N
0.3%

% C
66.5%

% H
6.8%

% S
0.3%

% O
26.1%

IAT (mg KOH/g)
142.1

13C NMR carbonyl and carboxyl
5.0%

13C NMR aromatics and olefinics
66.5%

13C NMR cyclooxygenated compounds
0.5%

13C NMR ethers, esters and hydroxy
1.5%

13C NMR alkyls
27.0%

TABLE 6

Result of the deasphalting process of the vacuum residue coprocessed

with the stream BIO B using pentane as solvent.

Percentage of BIO B coprocessed

10%
25%
33%
50%
75%

DEAO [%]
82.7%
72.3%
70.3%
57.5%
44.0%

Elemental analysis (% w/w)

% N
0.8%
0.7%
0.6%
0.5%
0.3%

% C
85.7%
84.6%
84.3%
82.5%
79.9%

% H
11.9%
11.6%
11.6%
10.9%
10.2%

% S
0.4%
0.3%
0.3%
0.3%
0.3%

% O
1.2%
2.8%
3.3%
5.7%
9.1%

RC TG CB [%]
4.2%
3.3%
3.1%
2.8%
2.5%

IAT (mg KOH/g)
0.67
1.53
3.11
5.52
8.30

13C NMR carbonyl
0.5%
0.5%
0.7%
0.5%
1.5%

and carboxyl

13C NMR aromatic
18.5%
21.2%
21.6%
26.1%
31.6%

and olefinics

13C NMR
0.5%
0.5%
0.5%
0.5%
0.5%

cyclooxygenated

compounds

13C NMR ethers,
0.5%
1.6%
1.6%
2.1%
2.3%

esters and

hydroxy

13C NMR alkyls
80.0%
76.2%
75.7%
71.8%
64.1%

Example 4—Comparison Between the Coprocessing of Vacuum Residue and a Lignocellulosic Liquid Stream (BIO A×BIO B) in a Deasphalting Process with LPG as Solvent

The vacuum residue characterized in Table 1 was coprocessed with 33 wt % of the stream resulting from the conversion of lignocellulosic biomass A and B (Tables 3 and 5) using LPG as solvent in the deasphalting process. The weight ratio of LPG to the combined feed was equal to five.

The extraction temperature was maintained at 65° C. and the system was pressurized so that the solvent was in the liquid phase. The system was stirred for 6 hours, and was then submitted to separation of the two phases by decanting for 15 hours.

The two fractions obtained were discharged from the system in the same condition of equilibrium proposed during the steps of extraction and decanting. The results are presented in Table 7.

TABLE 7

Result of the deasphalting process of the vacuum residue coprocessed

with stream BIO A or BIO B using LPG as solvent.

Results
33% BIO A
33% BIO B

DEAO [%]
51.7%
56.6%

Elemental analysis (% w/w)

% N
0.4%
0.4%

% C
85.2%
85.1%

% H
12.1%
11.6%

% S
0.3%
0.4%

% O
2.0%
2.5%

RC TG [%]
1.0%
1.1%

IAT (mg KOH/g)
3.94
6.49

13C NMR carbonyl
1.1%
1.5%

and carboxyl

13C NMR aromatic
16.2%
23.3%

and olefinics

13C NMR
0.5%
0.5%

cyclooxygenated

compounds

13C NMR ethers,
3.3%
3.8%

esters and

hydroxy

13C NMR alkyls
19.2%
71.4%

Example 5—Comparison Between the Coprocessing of Vacuum Residue and a Lignocellulosic Liquid Stream (BIO A×BIO B) in a Deasphalting Process with Pentane as Solvent

The vacuum residue characterized in Table 1 was coprocessed with 33%, 50% and 63% by weight of the stream resulting from the conversion of lignocellulosic biomass A and B (Tables 3 and 5) using pentane as solvent in the deasphalting process. The weight ratio of pentane to the combined feed was equal to five.

The two fractions obtained were discharged from the system in the same condition of equilibrium proposed during the steps of extraction and decanting.

The samples of extract were analyzed for carbon 14 for determining the contents of renewable carbon. The results are presented in Table 8.

TABLE 8

Analysis of the content of renewable carbon in the feed obtained

in the deasphalting process of the vacuum residue coprocessed

with stream BIO A or BIO B using pentane as solvent.

Results
50%
63%
33%
33%

Renewable feed
Bio B
Bio A
Bio B
Bio A

Total feed
100
100
100
100

Concentration
50
63
33
33

of renewable

feed [%]

% C renewable feed
66.5%
42.6%
66.5%
42.6%

Yield DEAO [%]
57.0
52.8
70.0
64.7

% C renewable
5.38%
5.88%
1.74%
1.15%

DEAO (¹⁴C)

Example 6—Process for Producing Liquid Fuels in an FCC Unit

Two series of tests were carried out with a stream of bio-oil, according to the following process stages for production of liquid motor fuels in the distillation range of gasoline and diesel:

A) deasphalting of the feed consisting of bio-oil, fed diluted in a liquid fossil hydrocarbon stream in contact with a solvent in the proportion from 0 wt % to 63 wt %, based on the weight of the combined feed of the fossil stream and the stream of bio-oil;

B) separation of the solvent and oil to obtain a liquid stream of deasphalted oil and recycling of the solvent, back to the deasphalting process and

C) catalytic cracking of the liquid fraction fed into the FCC reactor in a catalyst bed containing zeolite catalyst for maximizing liquid motor fuels in the distillation range of gasoline and diesel.

Table 9 describes the yields of deasphalting carried out at a temperature of 65° C., 1379 kPa and stirred for 6 hours, using pentane as solvent. The coprocessing was carried out with Lula vacuum residue in all the experiments.

TABLE 9

Yields of deasphalting using pentane as solvent.

DASF0
DASF1
DASF2
DASF3
DASF4
DASF5
DASF6

Fossil
Bio-oil
Bio-oil
Bio-oil
CPO
CPO
CPO

% Renewable
0
25
33
63
25
33
50

fed

Solvent
Pentane
Pentane
Pentane
Pentane
Pentane
Pentane
Pentane

% DEAO
88
72
65
52
74
70
57

% RASF
12
28
35
48
26
30
43

Table 10 shows characterization of the deasphalted oils thus produced, while Table 11 shows characterization of the heavy vacuum gas oil (HGO) Lula used in coprocessing with DEAO in catalytic cracking.

TABLE 10

Characterization of the deasphalted oils produced.

Bio-oil
DEAO0
DEAO1
DEAO2
DEAO3
DEAO4
DEAO5
DEAO6

Bio-oil
Fossil
Bio-oil
Bio-oil
Bio-oil
CPO
CPO
CPO

% Renewable
100
0
25
33
63
25
33
50

fed

RC TG,%
—
5.2
4.1
3.8
3.6
3.3
—
2.8

Naphtha TG,%
—
0.1
2.0
1.5
5.0
8.5
—
11.9

% N
—
0.8
0.5
0.7
0.5
0.7
0.6
0.6

% C
—
86.2
85.8
85.4
85.4
84.6
85.3
82.5

% H
—
11.9
11.7
11.7
11.5
11.6
11.6
10.9

% S
—
0.3
0.5
0.7
0.6
0.3
0.5
0.3

% O
—
0.8
1.5
1.5
2.0
2.8
2.0
5.7

IAT
—
0.0
3.51
4.92
10.27
1.53
3.11
5.52

NMR carbonyl +
—
0.5
0.5
0.0
—
0.5
0.5
0.5

carboxyl

NMR aromatics +
—
19.6
17.7
21.4
—
21.2
21.6
26.1

olefinlcs

NMR
—
0.5
0.5
0.0
—
0.5
0.5
0.5

cyclooxygenated

compounds

NMR ethers +
—
0.5
2.0
0.0
—
2.3
1.6
1.6

esters +

hydroxy

NMR alkyls
—
80.4
80.3
78.6
—
76.5
76.3
71.8

Na, mg/kg
5.4
16
<0.5
<0.5
10.7
—
<0.5
—

K, mg/kg
—
2.2
<1.0
<1.0
<1.0
—
<1.0
—

Ca, mg/kg
16
9.7
6.7
<0.5
5.0
—
<0.5
—

Fe, mg/kg
4.6
2.7
<0.5
<0.5
<0.5
2.0
<0.5
—

Mn, mg/kg
2.0
<0.5
<0.5
<0.5
<0.5
<0.5
<0.5
<0.5

TABLE 11

Characterization of the heavy vacuum gas oil (HGO) Lula

used in coprocessing with DEAO in catalytic cracking.

Density (d20/4)
0.9193

° API
21.8

RCR (wt %)
0.2
ASTM D524

Total Nitrogen (wt %)
0.205
ASTM D5762

Basic Nitrogen (mg/kg)
1131
UOP 269

Sulfur (wt %)
0.337
ASTM D5453

Viscosity at 60° C.
52.7
ASTM D445-1

(mm²/s)

Viscosity at 82.2° C.
21.2
ASTM D445-2

(mm²/s)

Viscosity at 100° C.
12.11
ASTM D445-3

(mm²/s)

Aniline Point (° C.)
90.35
ASTM D611

Metals

Na (mg/kg)
<0.5
N2440

Ca (mg/kg)
1.3
N2440

Ni (mg/kg)
<0.5
N2440

V (mg/kg)
<1
N2440

Fe (mg/kg)
1.4
N2440

Type of hydrocarbon - SFC

Saturates (wt %)
60.3
PE-4CE-00313 −= A

Monoaromatics (wt %)
17.5
PE-4CE-00313 −= A

Diaromatics (wt %)
14.6
PE-4CE-00313 −= A

Tri aromatics (wt %)
5.3
PE-4CE-00313 −= A

Polyaromatics (wt %)
2.3
PE-4CE-00313 −= A

C/H ratio - NMR
0.5465
HASAN, M.; FUEL, 62, 518-23

% C unsaturated
17
HASAN, M.; FUEL, 62, 518-23

% C saturated
83
HASAN, M.; FUEL, 62, 518-23

% H aromatic
3.4
HASAN, M.; FUEL, 62, 518-23

% H olefinic
0.1
HASAN, M.; FUEL, 62, 518-23

% H saturated
96.5
HASAN, M.; FUEL, 62, 518-23

The deasphalted oils (DEAO) shown in Table 10 were mixed with the heavy vacuum gas oil (HGO) from Table 11 in the proportion of 30% of DEAO to 70% of HGO, by weight, and were used as feed in a catalytic cracking unit at a reaction temperature of 535° C.

Table 12 presents data relating to the process for producing liquid fuels from a mixture of DEAO and HGO, in which DEAO 0 has 100% fossil origin.

TABLE 12

30% DEAO0 +
30% DEAO0 +
30% DEAO0 +
30% DEAO0 +
30% DEAO0 +

Feed
70% HGOLULA
70% HGOLULA
70% HGOLULA
70% HGOLULA
70% HGOLULA

Cracking
535
535
535
535
535

Temperature, ° C.

Cat/oil ratio
4.02
6.00
6.00
6.00
8.04

Conversion, wt %
69.50
77.87
74.55
78.47
78.95

Yield, wt %

Coke
6.52
8.82
7.75
9.62
10.29

Dry Gas
3.22
3.85
3.34
3.87
3.78

Hydrogen
0.18
0.18
0.17
0.18
0.15

H₂S
0.00
0.00
0.00
0.00
0.00

Methane
1.23
1.51
1.29
1.53
1.48

Ethane
0.97
1.06
0.96
1.07
1.03

Ethylene
0.84
1.10
0.92
1.08
1.12

CO
0.07
0.00
0.00
0.00
0.07

CO₂
0.12
0.20
0.18
0.18
0.29

LPG
14.39
18.88
16.49
18.74
18.98

Propane
1.28
1.96
1.51
2.00
1.98

Propylene
3.75
4.74
4.26
4.64
4.73

n-Butane
1.07
1.63
1.28
1.64
1.65

Isobutane
3.05
5.05
3.92
5.03
5.19

C4 Olefins
5.23
5.50
5.52
5.43
5.44

1-Butylene
1.18
1.30
1.27
1.27
1.27

Isobutylene
1.61
1.47
1.59
1.45
1.46

c-2-Butylene
1.14
1.28
1.24
1.26
1.27

t-2-Butylene
1.26
1.43
1.38
1.41
1.41

Butadiene
0.04
0.03
0.04
0.03
0.04

Gasoline
45.2
46.1
46.8
46.1
45.5

LCO
16.0
13.0
14.3
12.6
12.4

Base
14.5
9.1
11.2
8.9
8.6

Table 13 presents a summary of the results obtained by varying the catalyst/oil ratio obtained for a mixture of deasphalted oil and the heavy gas oil in Table 11 in the ratio of 30%/70% for the deasphalted oil (DEAO) and gas oil (HGO), respectively, the DEAO being obtained from 25% of bio-oil fed into the deasphalting process (DEAO1).

TABLE 13

30% DEAO1 +
30% DEAO1 +
30% DEAO1 +
30% DEAO1 +
30% DEAO1 +

Feed
70% HGOLULA
70% HGOLULA
70% HGOLULA
70% HGOLULA
70% HGOLULA

Cracking
535
535
535
535
535

temperature, ° C.

Catalyst/oil, w/w
4.02
6.00
6.00
6.00
8.04

Conversion, wt %
72.50
76.54
76.89
77.09
79.31

Yield, wt %

Coke
7.19
8.91
9.30
9.21
10.90

Dry Gas
3.45
3.68
3.80
3.73
4.02

Hydrogen
0.18
0.20
0.19
0.19
0.22

H₂S
0.00
0.00
0.00
0.00
0.00

Methane
1.36
1.46
1.51
1.48
1.62

Ethane
1.02
1.00
1.06
1.05
1.10

Ethylene
0.89
1.02
1.04
1.02
1.08

CO
0.07
0.07
0.08
0.08
0.09

CO₂
0.13
0.18
0.19
0.19
0.23

LPG
15.48
17.83
17.70
17.66
18.09

Propane
1.47
1.81
1.91
1.85
1.97

Propylene
3.96
4.49
4.38
4.41
4.51

n-Butane
1.21
1.53
1.58
1.55
1.60

Isobutane
3.46
4.72
4.76
4.69
4.83

C4 Olefins
5.38
5.27
5.06
5.16
5.18

1-Butylene
1.22
1.26
1.19
1.21
1.23

Isobutylene
1.60
1.40
1.33
1.37
1.39

c-2-Butylene
1.20
1.22
1.19
1.21
1.20

t-2-Butylene
1.33
1.37
1.33
1.35
1.35

Butadiene
0.03
0.01
0.03
0.02
0.03

Gasoline
46.2
45.9
45.8
46.2
46.0

LCO
15.0
13.6
13.6
13.6
12.4

Base
12.5
9.8
9.5
9.3
8.3

Table 14 presents a summary of the results obtained by varying the catalyst/oil ratio for a mixture of deasphalted oil and the heavy gas oil in Table 11 in the ratio of 30%/70% for the deasphalted oil (DEAO) and gas oil (HGO), respectively, the DEAO being obtained from 33% of bio-oil fed into the deasphalting process (DEAO2).

TABLE 14

30% DEAO2 +
30% DEAO2 +
30% DEAO2 +
30% DEAO2 +
30% DEAO2 +

Feed
70% HGOLULA
70% HGOLULA
70% HGOLULA
70% HGOLULA
70% HGOLULA

Cracking
535
535
535
535
535

Temperature, ° C.

Catalyst/oil, w/w
4.02
6.00
6.00
6.00
8.04

Conversion, wt %
73.02
77.24
76.84
77.21
79.94

Yield, wt %

Coke
7.68
9.24
8.95
9.17
11.60

Dry Gas
3.92
3.76
3.72
3.80
4.17

Hydrogen
0.21
0.20
0.19
0.19
0.18

H₂S
0.00
0.00
0.00
0.00
0.00

Methane
1.58
1.49
1.48
1.51
1.68

Ethane
1.17
1.03
1.05
1.07
1.17

Ethylene
0.96
1.04
1.01
1.04
1.15

CO
0.08
0.08
0.08
0.08
0.09

CO₂
0.17
0.19
0.19
0.19
0.34

LPG
15.67
18.10
17.51
17.74
18.85

Propane
1.75
1.94
1.89
1.95
2.35

Propylene
3.98
4.48
4.32
4.36
4.44

n-Butane
1.39
1.62
1.57
1.62
1.87

Isobutane
3.86
4.92
4.65
4.77
5.46

C4 Olefins
4.69
5.13
5.07
5.04
4.73

1-Butylene
1.11
1.22
1.20
1.19
1.10

Isobutylene
1.35
1.34
1.35
1.31
1.19

c-2-Butylene
1.02
1.21
1.18
1.19
1.14

t-2-Butylene
1.16
1.35
1.32
1.32
1.27

Butadiene
0.04
0.02
0.03
0.02
0.03

Gasoline
45.5
45.9
46.4
46.2
44.9

LCO
15.3
13.4
13.5
13.5
12.3

Base
11.7
9.3
9.6
9.3
7.7

Table 15 presents a summary of the results obtained by varying the catalyst/oil ratio for a mixture of deasphalted oil and the heavy gas oil in Table 11 in the ratio of 30%/70% for the deasphalted oil (DEAO) and gas oil (HGO), respectively, the DEAO being obtained from 63% of bio-oil fed into the deasphalting process (DEAO3).

TABLE 15

30% DEAO3 +
30% DEAO3 +
30% DEAO3 +
30% DEAO3 +

Feed name
70% HGOLULA
70% HGOLULA
70% HGOLULA
70% HGOLULA

Cracking Temp., ° C.
535
535
535
535

Cat/oil, w/w
6.00
6.00
6.00
8.04

Conversion, wt %
78.17
76.59
77.35
82.72

Yield, wt %

Coke
8.73
8.47
8.86
14.18

Dry Gas
3.90
3.68
3.76
4.81

Hydrogen
0.15
0.14
0.14
0.16

H₂S
0.00
0.00
0.00
0.00

Methane
1.54
1.45
1.49
1.96

Ethane
1.06
1.03
1.06
1.30

Ethylene
1.14
1.06
1.08
1.40

CO
0.14
0.15
0.14
0.15

CO₂
0.21
0.25
0.24
0.39

LPG
18.98
17.85
18.01
20.96

Propane
2.01
1.90
2.00
3.12

Propylene
4.81
4.49
4.46
4.49

n-Butane
1.65
1.56
1.62
2.32

Isobutane
5.09
4.71
4.88
6.88

C4 Olefins
5.41
5.19
5.05
4.15

1-Butylene
1.30
1.23
1.20
0.99

Isobutylene
1.42
1.38
1.31
1.01

c-2-Butylene
1.26
1.21
1.19
1.01

t-2-Butylene
1.42
1.35
1.33
1.13

Butadiene
0.02
0.03
0.02
0.02

Gasoline
46.2
46.2
46.3
42.2

LCO
12.8
13.7
13.4
11.0

Base
9.0
9.7
9.2
6.3

Total
100.00
100.00
100.00
100.00

Table 16 presents a summary of the results obtained by varying the catalyst/oil ratio for a mixture of deasphalted oil and the heavy gas oil in Table 11 in the ratio of 30%/70% for the deasphalted oil (DEAO) and gas oil (HGO), respectively, the DEAO being obtained from 25% of catalytic bio-oil fed into the deasphalting process (DEAO4).

TABLE 16

30% DEAO4 +
30% DEAO4 +
30% DEAO4 +
30% DEAO4 +
30% DEAO4 +

Feed
70% HGOLULA
70% HGOLULA
70% HGOLULA
70% HGOLULA
70% HGOLULA

Cracking
535
535
535
535
535

temperature, ° C.

Cat/oil, w/w
4.02
6.00
6.00
6.00
8.04

conversion, wt %
71.32
77.12
77.85
77.57
80.03

Yield, wt %

Coke
6.66
8.55
8.76
9.00
11.53

Dry Gas
3.31
3.63
3.67
3.65
3.89

Hydrogen
0.13
0.15
0.14
0.13
0.13

H₂S
0.00
0.00
0.00
0.00
0.00

Methane
1.31
1.42
1.44
1.43
1.53

Ethane
0.98
0.98
1.01
1.01
1.04

Ethylene
0.89
1.09
1.09
1.08
1.20

CO
0.00
0.07
0.07
0.07
0.09

CO₂
0.16
0.20
0.24
0.23
0.37

LPG
15.49
18.36
18.48
18.38
19.42

Propane
1.67
1.90
1.93
1.96
2.22

Propylene
3.81
4.66
4.65
4.56
4.70

n-Butane
1.37
1.58
1.60
1.62
1.81

Isobutane
3.89
5.06
5.01
5.06
5.74

C4 Olefins
4.74
5.16
5.29
5.18
4.95

1-Butylene
1.10
1.24
1.25
1.22
1.15

Isobutylene
1.32
1.35
1.38
1.35
1.26

c-2-Butylene
1.09
1.20
1.24
1.22
1.18

t-2-Butylene
1.22
1.35
1.39
1.37
1.33

Butadiene
0.02
0.02
0.02
0.02
0.02

Gasoline
45.7
46.3
46.6
46.2
44.7

LCO
16.1
13.4
12.9
13.2
11.9

Base
12.6
9.5
9.3
9.2
8.0

Table 17 presents a summary of the results obtained by varying the catalyst/oil ratio for a mixture of deasphalted oil and the heavy gas oil in Table 11 in the ratio of 30%/70% for the deasphalted oil (DEAO) and gas oil (HGO), respectively, the DEAO being obtained from 33% of catalytic bio-oil fed into the deasphalting process (DEAO5).

TABLE 17

30% DEAO5 +
30% DEAO5 +
30% DEAO5 +
30% DEAO5 +

Feed
70% HGO LULA
70% HGO LULA
70% HGO LULA
70% HGO LULA

Cracking
535
535
535
535

temperature, ° C.

Cat/oil, w/w
4.02
6.00
6.00
6.00

Conversion, wt %
68.76
75.10
75.60
73.45

Yield, wt %

Coke
6.41
9.24
9.16
8.12

Dry Gas
3.30
3.70
3.84
3.57

Hydrogen
0.17
0.19
0.19
0.17

H₂S
0.00
0.00
0.00
0.00

Methane
1.27
1.47
1.53
1.40

Ethane
1.02
1.05
1.10
1.04

Ethylene
0.83
0.99
1.01
0.95

CO
0.08
0.08
0.08
0.08

CO₂
0.19
0.26
0.23
0.26

LPG
13.94
17.00
17.08
16.48

Propane
1.39
1.96
1.98
1.76

Propylene
3.52
4.09
4.15
4.09

n-Butane
1.14
1.61
1.61
1.47

Isobutane
3.03
4.70
4.57
4.22

C4 Olefins
4.86
4.64
4.78
4.95

1-Butylene
1.11
1.10
1.13
1.16

Isobutylene
1.46
1.18
1.25
1.33

c-2-Butylene
1.07
1.10
1.12
1.15

t-2-Butylene
1.18
1.24
1.25
1.28

Butadiene
0.04
0.02
0.02
0.03

Gasoline
44.8
44.8
45.2
44.9

LCO
16.6
14.9
14.5
15.4

Base
14.6
10.0
9.9
11.1

Table 18 presents a summary of the results obtained by varying the catalyst/oil ratio for a mixture of deasphalted oil and the heavy gas oil in Table 11 in the ratio of 30%/70% for the deasphalted oil (DEAO) and gas oil (HGO), respectively, the DEAO being obtained from 50% of catalytic bio-oil fed into the deasphalting process (DEAO6).

TABLE 18

30% DEAO6 +
30% DEAO6 +
30% DEAO6 +
30% DEAO6 +
30% DEAO6 +

Feed
70% HGOLULA
70% HGOLULA
70% HGOLULA
70% HGOLULA
70% HGOLULA

Cracking
535
535
535
535
535

temperature, ° C.

Cat/oil, w/w
4.02
6.00
6.00
6.00
8.04

Conversion, wt %
72.17
75.78
76.04
76.63
77.32

Yield, wt %

Coke
6.22
8.35
8.39
8.68
9.80

Dry Gas
3.16
3.54
3.51
3.53
3.62

Hydrogen
0.10
0.12
0.11
0.11
0.10

H₂S
0.00
0.00
0.00
0.00
0.00

Methane
1.23
1.37
1.37
1.37
1.41

Ethane
0.92
0.95
0.96
0.96
0.98

Ethylene
0.91
1.10
1.08
1.09
1.15

CO
0.10
0.11
0.11
0.12
0.12

CO₂
0.18
0.27
0.29
0.27
0.37

LPG
15.53
18.22
17.82
17.98
18.26

Propane
1.53
1.86
1.85
1.87
2.09

Propylene
3.95
4.63
4.49
4.53
4.44

n-Butane
1.27
1.55
1.53
1.55
1.69

Isobutane
3.78
4.96
4.83
4.91
5.30

C4 Olefins
5.00
5.21
5.11
5.12
4.73

1-Butylene
1.15
1.25
1.20
1.20
1.12

Isobutylene
1.41
1.36
1.33
1.33
1.21

c-2-Butylene
1.14
1.22
1.20
1.21
1.12

t-2-Butylene
1.26
1.37
1.35
1.35
1.26

Butadiene
0.03
0.01
0.03
0.02
0.02

Gasoline
47.0
45.3
45.9
46.1
45.2

LCO
15.7
13.4
13.6
13.4
13.5

Base
12.1
10.8
10.3
9.9
9.2

Table 19 below presents the yields by weight obtained for each of the deasphalted oils (DEAO 0, DEAO 1, DEAO 2, DEAO 3 and DEAO 4) compared at constant yield of coke, which gives better simulation of a catalytic cracking unit on a commercial scale.

TABLE 19

Comparative data relating to the process for producing liquid

fuels from deasphalted oils DEAO 0, DEAO 1, DEAO 2 and DEAO 3.

FCC Feed

DEAO 0
DEAO 1
DEAO 2
DEAO 3
DEAO 4

Reference
Bio-oil
Bio-oil
Bio-oil
Bio-oil

Cracking temperature (° C.)
535
535
535
535
535

Conversion (wt %)
76.1
75.5
75.5
77.0
73.97

Conversion/(100-Conversion)
3.2
3.1
3.1
3.4
2.84

Catalyst/oil ratio (w/w)
5.9
5.3
5.1
5.9
5.64

Variation of coke (wt %)
1.4
1.6
1.7
1.4
1.51

Yields (wt %)

Coke
8.50
8.50
8.50
8.50
8.50

Dry gas
3.60
3.65
3.83
3.73
3.32

Hydrogen
0.17
0.19
0.20
0.14
0.16

Hydrogen sulfide
0.00
0.00
0.00
0.00

Methane
1.40
1.45
1.53
1.47
1.30

Ethane
1.02
1.03
1.10
1.04
0.96

Ethylene
1.01
0.98
1.00
1.08
0.91

CO
0.00
0.08
0.08
0.14
0.04

CO₂
0.19
0.16
0.15
0.24
0.22

LPG
17.46
16.83
17.00
18.08
15.48

Propane
1.72
1.71
1.85
1.93
1.51

Propylene
4.41
4.26
4.21
4.57
4.01

n-Butane
1.44
1.42
1.51
1.58
1.28

Isobutane
4.36
4.23
4.37
4.80
3.81

C₄Olefins
5.53
5.20
5.05
5.20
4.86

1-Butylene
1.28
1.22
1.20
1.23
1.16

Isobutylene
1.55
1.40
1.37
1.37
1.32

cis-2-Butylene
1.26
1.21
1.16
1.21
1.13

trans-2-Butylene
1.40
1.35
1.30
1.36
1.23

Butadiene
0.03
0.02
0.03
0.03
0.02

Gasoline
46.31
46.33
45.90
46.36
46.42

LCO
13.72
14.09
14.18
13.47
14.91

Heavy compounds
10.23
10.36
10.36
9.48
11.12

Total
100.00
100.00
100.00
100.00
100.00

As can be seen from Table 19, the yields of gasoline and LCO obtained using deasphalted oil comprising renewable carbon (DEAO 1, DEAO 2, DEAO 3 and DEAO 4) are very similar to those obtained with the reference of fossil origin (DEAO 0).

There are other positive points with respect to the use of the deasphalted oil stream comprising carbon of renewable origin.

It can be seen that there is not a pronounced increase in the yield of coke, which would affect the other yields in FCC.

Furthermore, production of water was not observed in the catalytic cracking process. The increases of carbon monoxide and dioxide were slight when compared to those normally obtained with pure bio-oil in this process, which reduces the occurrence of corrosion in the top system of the main fractionator.

As an additional advantage, the DEAO stream of partially renewable origin fed into the FCC process has a content of alkali metals and alkaline-earth metals lower than is contained in a conventional bio-oil. This avoids possible effects on the stability of the zeolite catalyst used in the process.

The description given up to here of the subject matter of the present invention must be considered only as one possible embodiment or possible embodiments, and any particular features introduced therein are only to be understood as something that was written to facilitate understanding. Accordingly, they cannot be considered in any way as limiting the invention, which is limited to the scope of the claims given hereunder.

Example 7—Coprocessinq of Vacuum Residue and a Lignocellulosic Liquid Stream C (BIO C) in a Deasphalting Process with Pentane as Solvent

The vacuum residue characterized in Table 1 was coprocessed with 25 wt % of the stream resulting from the conversion of lignocellulosic biomass C (BIO C) using pentane as solvent in the deasphalting process. The characterization of the stream BIO C is shown in Table 20. The weight ratio of pentane to the combined feed was equal to five.

The two fractions obtained were discharged from the system in the same condition of equilibrium proposed during the steps of extraction and decanting. The results are presented in Table 21.

TABLE 20

Characterization of the stream BIO C.

Analysis
BIO C

RC TG [%]

Elemental analysis (% w/w)

% N
0.4%

% C
69.9%

% H
6.9%

% S
<0.3%

% O
22.8%

IAT (mg KOH/g)

13C NMR carbonyl and carboxyl
2.9%

13C NMR aromatics and olefinics
53.8%

13C NMR cyclooxygenated compounds
<0.5%

13C NMR ethers, esters and hydroxy
5.3%

13C NMR alkyls
37.7%

TABLE 21

Result of the deasphalting process of the vacuum residue coprocessed

with the stream BIO C using pentane as solvent.

Percentage of BIO C coprocessed

25%

DEAO [%]
74.7%

Elemental analysis (% w/w)

% N
0.8

% C
86.7

% H
11.8

% S
<0.3

% O
1.5

RC TG [%]
—

IAT (mg KOH/g)
—

13C NMR carbonyl and carboxyl
<0.5%

13C NMR aromatics and olefinics
24.2%

13C NMR cyclooxygenated compounds
<0.5%

13C NMR ethers, esters and hydroxy
<0.5%

13C NMR alkyls
75.8%

Claims

1. A coprocessing of a lignocellulosic liquid stream and an intermediate fossil stream in the oil refining process, comprising: contacting said intermediate fossil stream and said lignocellulosic liquid stream with a stream of solvent of C3-C10 hydrocarbons in an extraction section, obtaining a stream of extract with solvent and a stream of raffinate with solvent, in which the extraction section is a deasphalting unit; andsending said stream of extract with solvent to a separation section, obtaining a deasphalted oil stream comprising solvent-free carbon of renewable origin and a stream of recovered solvent.
2. The coprocessing as claimed in claim 1, comprising: separating the stream of raffinate with solvent into a stream of recovered solvent and a stream of asphaltic residue in a separation section.
3. The coprocessing as claimed in claim 1, wherein said lignocellulosic liquid stream consists of bio-oil.
4. The coprocessing as claimed in claim 1, wherein said intermediate fossil stream consists of vacuum residue.
5. The coprocessing as claimed in claim 1, wherein said hydrocarbon solvent consists of C3-C7 hydrocarbons.
6. The coprocessing as claimed in claim 1, wherein said hydrocarbon solvent is derived from oil refining processes.
7. The coprocessing as claimed in claim 1, wherein said solvent of hydrocarbons is selected from liquefied petroleum gas (LPG) and pentane.
8. The coprocessing as claimed claim 1, wherein said stream of recovered solvent is recycled to the extraction section, in which the solvent stream is mixed with the solvent stream.
9. The coprocessing as claimed claim 1, wherein said contact between said stream of solvent of hydrocarbons or the mixture of the solvent streams and the combined feed consisting of the lignocellulosic liquid stream and intermediate fossil stream in the extraction section takes place at a weight ratio between 0.5 and 10, preferably between 3 and 6.
10. The coprocessing as claimed in claim 1, wherein said lignocellulosic liquid stream corresponds to 0.1 to 99.9 wt %, preferably between 10 and 75 wt %, relative to the amount of total feed added to the extraction section.
11. The coprocessing as claimed in claim 1, wherein said contacting between said stream of solvent of hydrocarbons or said mixture of the solvent streams and the combined feed in the extraction section takes place in the temperature range between 60° C. and 120° C. and in the pressure range between 100 and 10 000 kPa.
12. The coprocessing as claimed in claim 1, wherein said lignocellulosic liquid stream is derived from natural raw materials selected from starch, cellulose and hemicellulose obtained from leaves and bagasse, and sugars, such as sugar cane.
13. The coprocessing as claimed in claim 12, wherein said lignocellulosic liquid stream is obtained from the pulp and paper industry from the Kraft route.
14. A process for producing fuels from a deasphalted oil stream obtained by coprocessing comprising sending the deasphalted oil stream comprising carbon of renewable origin to a conversion section of an oil refinery selected from catalytic hydrocracking unit, HDT, thermal cracking, fluidized-bed catalytic cracking, visbreaking, delayed coking and catalytic reforming.
15. The process of claim 14, wherein said deasphalted oil stream is mixed with an intermediate fossil stream in said conversion section 20 or before it is sent to the conversion section in a proportion in the range from 30 to 70 wt %, based on the weight of the total feed fed into the conversion section.
16. The process of claim 14, wherein said conversion section is a unit for fluidized-bed catalytic cracking, in which said unit comprises a reaction section, a rectification section and a catalyst regeneration section.
17. The process of claim 16, wherein said reaction section operates in a temperature range between 400 and 700° C., preferably between 420° C. and 620° C., having a residence time that varies between 1 and 10 seconds and with steam injection between 5 and 50 wt %, based on the total feed fed into the reaction section.
18. The process of claim 16, wherein a product from the reaction section is a stream comprising a cracked effluent and a spent catalyst, in which said product is sent to the rectification section for separating the cracked effluent from the clean spent catalyst.
19. The process of claim 18, wherein said stream comprising the cracked effluent and the spent catalyst is separated by cyclones.
20. The process of claim 19, wherein said cracked effluent is gasoline, diesel or fuel oil.
21. The process of claim 18, wherein said clean spent catalyst is sent to the catalyst regeneration section, in which combustion gases are generated after combustion of the catalyst with an air stream.
22. The process of claim 21, wherein the regenerated catalyst returns to the reaction section.

Priority Claims (1)

Number	Date	Country	Kind
BR 102018014578-9	Jul 2018	BR	national

PCT Information

Filing Document	Filing Date	Country	Kind
PCT/BR2019/050276	7/16/2019	WO	00

A PROCESS OF COPROCESSING A LIGNOCELLULOSIC LIQUID STREAM AND AN INTERMEDIATE FOSSIL STREAM IN AN OIL REFINING PROCESS AND A PROCESS FOR PRODUCING FUEL FROM A DEASPHALTED OIL STREAM

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Priority Claims (1)

PCT Information