Methods for processing a hydrocarbon oil feed stream utilizing a delayed coker, steam enhanced catalytic cracker, and an aromatics complex

Patent metadata

Field	Value
Publication number	US-12227708-B2
Application number	US-202217866029-A
Country	US
Kind code	B2
Filing date	Jul 15, 2022
Priority date	Jul 15, 2022
Publication date	Feb 18, 2025
Grant date	Feb 18, 2025

Abstract

An integrated process for upgrading a hydrocarbon oil feed stream utilizing a delayed coker, steam enhanced catalytic cracker, and an aromatics complex includes solvent deasphalting the hydrocarbon oil stream; delayed coking the heavy residual hydrocarbons; hydrotreating the delayed coker product stream and the deasphalted oil stream to form a C 3 -C 4 hydrocarbon stream, a light C 5+ hydrocarbon stream, and a heavy C 5+ hydrocarbon stream; dehydrogenating the C 3 -C 4 hydrocarbon stream to form propylene and butylene; steam enhanced catalytically cracking the light C 5+ hydrocarbon stream; steam enhanced catalytically cracking the heavy C 5+ hydrocarbon stream; passing at least a portion of the light steam enhanced catalytically cracked stream, the heavy steam enhanced catalytically cracked stream, or both to a product separator to produce a olefin product stream, a naphtha product stream, and a BTX product stream; and processing the naphtha product stream in the aromatics complex to produce benzene and xylenes.

First claim

What is claimed is:

1. An integrated process for upgrading a hydrocarbon oil feed stream utilizing a delayed coker, steam enhanced catalytic cracker, a dehydrogenation unit, and an aromatics complex, the method comprising:
solvent deasphalting the hydrocarbon oil stream to form at least a deasphalted oil stream and heavy residual hydrocarbons, the heavy residual hydrocarbons comprising at least asphaltenes;
delayed coking the heavy residual hydrocarbons to form petroleum coke and a delayed coker product stream;
hydrotreating the delayed coker product stream and the deasphalted oil stream to form a C 3 -C 4 hydrocarbon stream, a light C 5+ hydrocarbon stream, and a heavy C 5+ hydrocarbon stream;
dehydrogenating the C 3 -C 4 hydrocarbon stream to form propylene and butylene;
steam enhanced catalytically cracking the light C 5+ hydrocarbon stream in a first steam enhanced catalytic cracker to form a light steam enhanced catalytically cracked product comprising olefins, BTX, naphtha, or combinations thereof;
steam enhanced catalytically cracking the heavy C 5+ hydrocarbon stream in a second steam enhanced catalytic cracker to form a heavy steam enhanced catalytically cracked product comprising olefins, BTX, naphtha, or combinations thereof; passing at least a portion of the light steam enhanced catalytically cracked stream, the heavy steam enhanced catalytically cracked stream, or both to a product separator to produce a olefin product stream, a naphtha product stream, and a BTX product stream;
passing the naphtha product stream directly to an aromatics complex; and
processing the naphtha product stream in the aromatics complex to produce benzene and xylenes, and wherein
a first ratio of gas hourly space velocity of steam to gas hourly space velocity of light C 5+ hydrocarbon stream in the first steam enhanced catalytic cracker is less than a second ratio of gas hourly space velocity of steam to heavy C 5+ hydrocarbon stream in the second steam enhanced catalytic cracker,
the first ratio is from 0.2 to 0.8, and
the second ratio is from 0.8 to 1.0.

2. The process of claim 1 , wherein processing the naphtha product stream in the aromatics complex further comprises:
catalytically reforming the naphtha product stream to produce a reformate stream comprising benzene, toluene, and xylene; and
upgrading the toluene in the reformate stream in a transalkylation unit to form additional benzene, xylenes, or both.

3. The process of claim 1 , wherein
the light C 5+ hydrocarbon fraction comprises C 5+ hydrocarbons having a T 95 boiling point of less than 200° C.; and
the heavy C 5+ hydrocarbon fraction comprises C 5+ hydrocarbons having a T 5 boiling point of greater than or equal to 200° C.

4. The process of claim 1 , wherein hydrotreating the delayed coker product stream and the deasphalted oil stream additionally forms a C 1 hydrocarbon stream and a C 2 -C 4 hydrocarbon stream; and
the C 1 hydrocarbon stream, the C 2 -C 4 hydrocarbon stream, the light C 5+ hydrocarbon stream, and the heavy C 5+ hydrocarbon stream together comprise a hydrotreated product stream.

5. The process of claim 4 , further comprising:
methane cracking the C 1 hydrocarbon stream to form hydrogen;
steam cracking the C 2 -C 4 hydrocarbon stream to form a steam cracked product stream comprising olefins, naphtha, and BTX;
passing the steam cracked product stream to the product separator to thereby separate the olefins, the naphtha, and the BTX, and to thereby produce the olefin product stream, the naphtha product stream, the BTX product stream, and one or more product separator recycle streams, wherein the one or more product separator recycle stream comprise a methane recycle stream, a steam cracker recycle stream, a hydrotreater recycle stream a delayed coker recycle stream, or combinations thereof;
hydrotreating the hydrotreater recycle stream to form additional C 1 hydrocarbon stream, C 2 -C 4 hydrocarbon stream, light C 5+ hydrocarbon stream, heavy C 5+ hydrocarbon stream, or combinations thereof, wherein the hydrotreater recycle stream comprises cracked naphtha and light cycle oil having boiling points of between 185° C. to 426° C.;
delayed coking the delayed coker recycle stream to form additional delayed coker product stream, wherein the delayed coker recycle stream comprises heavy cycle oil having boiling points of between 426° C. to 650° C.;
methane cracking the methane recycle stream to form additional hydrogen;
steam cracking the steam cracker recycle stream to form additional steam cracked product, wherein the steam cracker recycle stream comprises C 2 -C 4 hydrocarbons; and
passing the hydrogen to the hydrotreater to be recycled in the hydrotreater.

6. The process of claim 5 , further comprising:
processing the naphtha product stream in the aromatics complex, wherein processing the naphtha product stream in the aromatics complex further comprises:
catalytically reforming the naphtha to produce a reformate stream comprising benzene, toluene, and xylene,
passing at least a portion of the reformate stream through one or more extractive distillation units to separate the benzene, toluene, and xylenes, produce a C 1 -C 4 hydrocarbon recycle stream, and produce a C 9+ hydrocarbon stream, and
upgrading the toluene in a transalkylation unit to form additional benzene, xylenes, or both;

passing the C 1 -C 4 hydrocarbon recycle stream to the product separator to produce additional methane recycle stream, additional steam cracker recycle stream, or both; and
passing the C 9+ hydrocarbon stream to the hydrotreater to produce additional C 1 hydrocarbon stream, C 2 -C 4 hydrocarbon stream, light C 5+ hydrocarbon stream, heavy C 5+ hydrocarbon stream, or combinations thereof.

7. The process of claim 1 , further comprising
initially passing the hydrocarbon oil stream through a feed separator to separate the hydrocarbon oil stream into at least a heavy hydrocarbon fraction, a feed middle distillate stream, and a feed naphtha stream;
solvent deasphalting the heavy hydrocarbon fraction to form at least the deasphalted oil stream and the heavy residual hydrocarbons;
steam enhanced catalytically cracking at least the feed middle distillate stream in the first steam enhanced catalytic cracker to form the light steam enhanced catalytically cracked product; and
processing the feed naphtha stream in the aromatics complex to produce additional benzene and xylenes.

8. The process of claim 1 , wherein the hydrocarbon oil stream comprises whole crude oil or crude oil fractions.

9. The process of claim 6 , wherein:
the solvent deasphalting unit is operated at a temperature of from 60° C. to 90° C. and a pressure of from 0.1 MPa to 0.4 MPa;
the delayed coker is operated at a temperature of from 450° C. to 600° C. and a pressure of from 0.1 MPa to 0.4 MPa;
the hydrotreating zone is operated at a temperature of from 370° C. to 500° C. and a pressure of from 0.1 MPa to 0.2 MPa;
the steam enhanced catalytic cracking system is operated at a temperature of from 525° C. to 750° C. and a pressure of from 0.1 MPa to 0.2 MPa;
the methane cracking zone is operated at a temperature of from 850° C. to 1200° C. and a pressure of from 0.1 MPa to 0.2 MPa;
the dehydrogenation unit is operated at a temperature of from 300° C. to 800° C. and a pressure of from 0.001 MPa to 1 MPa;
the steam cracking zone is operated at a temperature of from 800° C. to 950° C. and a pressure of from 0.1 MPa to 0.2 MPa;
the catalytic reformer is operated at a temperature of from 450° C. to 600° C. and a pressure of from 0.7 MPa to 7 MPa; and
the transalkylation unit is operated at a temperature of from 350° C. to 450° C. and a pressure of from

Assignees

• Saudi Arabian Oil Co

Inventors

• Xu Qi
• Akah Aaron Chi
• Al-Ghrami Musaed Salem
• Zhang Zhonglin

Classifications

• C10G2400/30

  Aromatics · CPC title

• C10G2400/20

  C2-C4 olefins · CPC title

• C10G2300/807

  Steam · CPC title

• C10G2300/4018

  Spatial velocity, e.g. LHSV, WHSV · CPC title

• C01B2203/1628

  Controlling the pressure · CPC title