Combination hydroconversion, fluid coking and gasification

• US 4,169,038 A
• Filed: 03/24/1978
• Issued: 09/25/1979
• Est. Priority Date: 03/24/1978
• Status: Expired due to Term

• Current Assignee: Exxon Research and Engineering Company (Exxon Mobil Corporation)
• Original Assignee: Exxon Research and Engineering Company (Exxon Mobil Corporation)
• Inventors: Bearden, Roby Jr., Aldridge, Clyde L., Metrailer, William J.
• Primary Examiner(s): Levine, Herbert
• Application Number:
  US05/889,744
• Time in Patent Office: 550 Days
• Field of Search: 208/50, 208/127, 208/8 R, 208/10
• US Class Current: 208/408
• CPC Class Codes: C10B 55/10 according to the "fluidised bed" technique
• CPC Class Codes: C10G 1/002 in combination with oil conversion- or refining processes
• CPC Class Codes: C10G 1/08 with moving catalysts
• CPC Class Codes: C10G 1/086 Characterised by the catalyst used
• CPC Class Codes: C10G 69/06 including at least one step of thermal cracking in the absence of hydrogen
• CPC Class Codes: C10J 2300/0906 Physical processes, e.g. shredding, comminuting, chopping, sorting
• CPC Class Codes: C10J 2300/093 Coal
• CPC Class Codes: C10J 2300/0946 Waste, e.g. MSW, tires, glass, tar sand, peat, paper, lignite, oil shale
• CPC Class Codes: C10J 2300/0956 Air or oxygen enriched air
• CPC Class Codes: C10J 2300/0959 Oxygen
• CPC Class Codes: C10J 2300/0976 as steam
• CPC Class Codes: C10J 2300/0986 Catalysts
• CPC Class Codes: C10J 2300/1807 Recycle loops, e.g. gas, solids, heating medium, water
• CPC Class Codes: C10J 2300/1884 with one stream being synthesis gas
• CPC Class Codes: C10J 3/503 for gasifiers with stationary fluidised bed
• CPC Class Codes: C10J 3/54 Gasification of granular or pulverulent fuels by the Winkler technique, i.e. by fluidisation
• CPC Class Codes: C10J 3/66 by introducing them into the gasification zone
• CPC Class Codes: C10J 3/78 High-pressure apparatus
• CPC Class Codes: C10J 3/84 with means for removing dust or tar from the gas
• CPC Class Codes: Y10S 208/951 Solid feed treatment with a gas other than air, hydrogen or steam

Abstract

A combination slurry hydroconversion, coking and coke gasification process is provided wherein solid fines having an average particle size of less than 10 microns in diameter or the ashes thereof recovered from a gaseous product derived from the coke gasification are used as a catalyst in the hydroconversion stage.

Claims

1. A process for upgrading a liquid-comprising carbonaceous chargestock which comprises:

(a) adding to said chargestock catalytic solids consisting essentially of carbonaceous fines resulting from step (k) to form a mixture, said fines having an average particle size of less than about 10 microns in diameter and a surface area of less than about 50 m² /g;

(b) reacting the chargestock containing said catalytic fines with a molecular hydrogen-containing gas under hydroconversion conditions in a hydroconversion zone to produce a hydrocarbonaceous oil product;

(c) separating a heavy oil fraction from said hydrocarbonaceous oil product;

(d) contacting at least a portion of said separated heavy oil fraction with a bed of fluidized solids maintained in a fluid coking zone under fluid coking conditions to form coke, said coke depositing on said fluidized solids;

(e) introducing a portion of said solids with a coke deposition thereon into a heating zone operated at a temperature greater than said coking zone temperature to heat said portion of solids;

(f) recycling a first portion of heated solids from said heating zone to said coking zone;

(g) introducing a second portion of said heated solids to a fluid bed gasification zone maintained at a temperature greater than the temperature of said heating zone;

(h) reacting said second portion of heated solids in said gasification zone with steam and a molecular oxygen-containing gas to produce a hot gaseous stream containing hydrogen;

(i) introducing said hot gaseous stream containing hydrogen and entrained solids into said heating zone;

(j) recovering from said heating zone the resulting cooled gaseous stream containing hydrogen and entrained solid carbonaceous fines, and

(k) separating at least a portion of said solid carbonaceous fines from said cooled gaseous stream, said separated fines having an average particle size of less than about 10 microns in diameter.

2. The process of claim 1 wherein prior to step (b), said mixture of chargestock and carbonaceous fines is treated with a gas comprising hydrogen and from about 1 to about 90 mole percent hydrogen sulfide.

3. The process of claim 2 wherein said treatment is conducted at a temperature ranging from about 615°

to about 980°

F. and at a pressure ranging from about 500 to about 5000 psig.

4. The process of claim 1 wherein prior to adding said catalytic solid carbonaceous fines to said chargestock, the fines are burned to reduce the concentration of carbon of said fines and to produce an ash and, thereafter, the resulting ash is added to said chargestock.

5. The process of claim 1 wherein said catalytic solid fines are added to said chargestock in an amount sufficient to provide from about 0.1 to 20 weight percent solid fines, based on said chargestock.

6. The process of claim 1 wherein said catalytic solid fines are added to said chargestock in an amount sufficient to provide from about 0.5 to about 10 weight percent solid fines, based on said chargestock.

7. The process of claim 1 wherein said catalytic solid fines are added to said chargestock in an amount sufficient to provide from about 1 to about 5 weight percent solid fines, based on said chargestock.

8. The process of claim 1 wherein said hydroconversion conditions include a temperature ranging from about 650°

F. to about 1000°

F. and a hydrogen partial pressure ranging from about 500 psig to about 5000 psig.

9. The process of claim 1 wherein said hydroconversion conditions include a temperature ranging from about 790°

to about 900°

F. and a hydrogen partial pressure ranging from about 1000 to about 3000 psig.

10. The process of claim 1 wherein said fluid coking conditions include a temperature ranging from about 850°

to about 1400°

F. and a pressure ranging from about 5 to about 150 psig.

11. The process of claim 1 wherein said gasification conditions include a temperature ranging from about 1200°

to about 2000°

F. and a pressure ranging from about 5 to about 150 psig.

12. The process of claim 1 wherein said chargestock comprises a hydrocarbonaceous oil.

13. The process of claim 1 wherein said chargestock comprises coal.

14. The process of claim 1 wherein other catalytic compounds are added to said chargestock.