Patent Application
20080135456
This invention relates to an improved fluidized coking process wherein an effective amount of a basic material, preferably an alkali or alkaline-earth metal-containing compound, is added to the coking zone to mitigate agglomeration of the coke during the coking of a heavy hydrocarbonaceous feedstock to produce lower boiling products.
Fluidized coking is a well established petroleum refinery process in which a heavy petroleum feedstock, typically a non-distillable residue (resid) from atmospheric and/or vacuum fractionation, are converted to lighter, more valuable materials by thermal decomposition (coking) at temperatures from about 900° F. (482° C.) to about 1100° F. (593° C.). Conventional fluid coking is performed in a process unit comprised of a coking reactor and a heater or burner. A petroleum feedstock is injected into the reactor in a coking zone comprised of a fluidized bed of hot, fine, coke particles and is distributed relatively uniformly over the surfaces of the coke particles where it is cracked to vapors and coke. The vapors pass through a gas/solids separation apparatus, such as a cyclone, which removes most of the entrained coke particles. The vapor is then discharged into a scrubbing zone where the remaining coke particles are removed and the products cooled to condense the heavy liquids. The resulting slurry, which usually contains from about 1 to about 3 wt. % coke particles, is recycled to extinction to the coking zone. The balance of the vapors go to a fractionators for separation of the gases and the liquids into different boiling fractions.
Some of the coke particles in the coking zone flow downwardly to a stripping zone at the base of the reactor vessel where steam removes interstitial product vapors from, or between, the coke particles, and some adsorbed liquids from the coke particles. The coke particles then flow down a stand-pipe and into a riser that moves them to a burning, or heating zone, where sufficient air is injected to burn at least a portion of the coke and heating the remainder sufficiently to satisfy the heat requirements of the coking zone where the unburned hot coke is recycled. Net coke, above that consumed in the burner, is withdrawn as product coke.
Another type of fluid coking employs three vessels: a coking reactor, a heater, and a gasifier. Coke particles having carbonaceous material deposited thereon in the coking zone are passed to the heater where a portion of the volatile matter is removed. The coke is then passed to the gasifier where it reacts, at elevated temperatures, with air and steam to form a mixture of carbon monoxide, carbon dioxide, methane, hydrogen, nitrogen, water vapor, and hydrogen sulfide. The gas produced in the gasifier is passed to the heater to provide part of the reactor heat requirement. The remainder of the heat is supplied by circulating coke between the gasifier and the heater. Coke is also recycled from the heater to the coking reactor to supply the heat requirements of the reactor.
The rate of introduction of resid feedstock to a fluid coker is limited by the rate at which it can be converted to coke. The major reactions that produce coke involve cracking of aliphatic side chains from aromatic cores, demethylation of aromatic cores and aromatization. The rate of cracking of aliphatic side chains is relatively fast and results in the buildup of a sticky layer of methylated aromatic cores. This layer is relatively sticky at reaction temperature. The rate of de-methylation of the aromatic cores is relatively slow and limits the operation of the fluid coker. At the point of fluid bed bogging, the rate of sticky layer going to coke equals the rate of introduction of coke precursors from the resid feed. An acceleration of the reactions involved in converting the sticky material to dry coke would allow increased reactor throughput at a given temperature or coking at a lower temperature at constant throughput. Less gas and higher quality liquids are produced at lower coking temperatures. Sticky coke particles can agglomerate (become heavier) and be carried under into the stripper section and cause fouling. When carried under, much of the sticky coke is sent to the burner, where this incompletely demethylated coke evolves methylated and unsubstituted aromatics via thermal cracking reactions that ultimately cause foaming problems in the acid gas clean-up units.
Therefore, there remains a need in the art for improved fluid coking processes that are capable of overcoming the problems associated with the formation of sticky material.
In accordance with the present invention there is provided a process for converting a heavy hydrocarbonaceous feedstock to lower boiling products, which process is performed in a fluid coking process unit comprised of a fluid coking reactor and a heater, said fluid coking reactor containing a coking zone, a scrubbing zone located above said coking zone for collecting vapor phase products, and a stripping zone, located below the coking zone, for stripping hydrocarbons from solid particles passing downwardly through the stripping zone, which process comprises:
(a) introducing the heavy hydrocarbonaceous feedstock having a Conradson carbon content of at least about 5 wt. % and an effective amount of a basic material containing an alkali metal, an alkaline-earth metal or combinations thereof, into said coking zone containing a fluidized bed of solid particles and maintained at effective coking temperatures and pressures, wherein there is produced a vapor phase product, including normally liquid hydrocarbons, and where coke is deposited on said solid particles;
(b) passing said vapor phase product to said scrubbing zone;
(c) passing said solid particles from said coking zone, with coke deposited thereon, downwardly through said coking zone, past said stripping zone, thereby stripping hydrocarbons from the solid particles with a stripping agent, wherein the stripped solid particles exit said fluid coking reactor and are passed into said heating zone which contains a fluidized bed of solid particles and which is operated at a temperature greater than that of the coking zone; and
(d) recycling at least a portion of the solid particles from the heating zone to the coking zone.
In a preferred embodiment the feedstock is selected from the group consisting of heavy and reduced petroleum crudes, petroleum atmospheric distillation bottoms, petroleum vacuum distillation bottoms, pitch, asphalt, tar sands, bitumen, and liquid products derived from a coal liquefaction process or an oil shale conversion process.
In another preferred embodiment of the present invention the basic material is one containing at least one alkali metal selected from Na and K.
In yet another preferred embodiment, the basic material is one containing at least one alkaline-earth metal selected from Ca and Mg.
In still other preferred embodiments the basic material is an alkali or alkaline-earth compound selected from oxides, hydroxides, carbonates, acetates, cresylates and alkyl and aryl carboxylates.
Any heavy hydrocarbonaceous material typically used in a coking process can be used herein. Generally, the heavy hydrocarbonaceous material will have a Conradson carbon residue of about 5 to 40 wt. % and be comprised of moieties, the majority of which boil above about 975° F. (524° C.). Suitable hydrocarbonaceous materials include heavy petroleum crudes, petroleum atmospheric distillation bottoms, petroleum vacuum distillation bottoms, pitch, asphalt, bitumen, liquid products derived from coal liquefaction processes, including coal liquefaction bottoms, liquid products derived from oil shale processing and mixtures thereof.
A typical heavy hydrocarbonaceous feedstock suitable for the practice of the present invention will typically have a composition and properties within the ranges set forth below.
Conradson Carbon 5 to 40 wt. %
Sulfur 1.5 to 8 wt. %
Hydrogen 9 to 11.5 wt. %
Nitrogen 0.2 to 2 wt. %
Carbon 70 to 90 wt. %
Metals 1 to 2000 wppm
Boiling Point 340° C.+ to 650° C.+
Specific Gravity −10 to 35° API
As previously mentioned, the rate of introduction of resid feedstock onto bed coke particles in a fluid coker reactor is limited by the rate at which it can be converted to coke. The major reactions that produce coke involve cracking of aliphatic side chains from aromatic cores, demethylation of aromatic cores, cyclic dehydrogenation reactions and aromatization. The rate of cracking of aliphatic side chains (>Cl), to produce liquids and gases including methane, is relatively fast and results in the buildup of a sticky layer of methylated aromatic cores on the bed coke particles. This layer is relatively sticky at reaction temperature. Sticky coke particles can agglomerate (become heavier) and be carried under into the stripper section and cause fouling, e.g., of the stripper sheds. De-methylation of aromatic cores produces methane and a less sticky coke. At the point of fluid bed bogging, the rate of sticky layer going to coke equals the rate of introduction of coke precursors from the resid feed. Practice of the instant invention results in an acceleration of the reactions involved in converting the sticky material to dry coke and thus allows increased reactor throughput at a given temperature or coking at a lower temperature at constant throughput. Less gas and higher quality liquids are produced at lower coking temperatures.
The process of the present invention will generally be conducted by introducing, into the coking zone with the hydrocarbonaceous feedstock, an effective amount of a basic material, which basic material is comprised of at least one basic alkali metal-containing compounds, or at least one alkaline earth-containing compounds, or a combination thereof. By effective amount we mean at least that amount that will result in a substantial increase in the rate of the formation of methane and dry coke material from the sticky material on the coke particles. This amount will typically be from about 100 to about 10,000 wppm, preferably from about 200 to about 5,000 wppm, and more preferably from about 250 to 3,000 wppm alkali and/or alkaline-earth metal containing compound. The preferred alkali metal compounds are Na and K basic compounds and mixtures thereof (e.g., K2CO3 and/or KOH) and the preferred alkaline-earth metal compounds are Ca and Mg basic compounds. Non-limiting examples of such compounds include the hydroxides, carbonates and acetates as well as alkyl and aryl carboxylates.
Reference is now made to
A fluidizing gas e.g., steam, is introduced at the base of coker reactor 1, through line 16, in an amount sufficient to obtained superficial fluidizing velocity in the range of about 0.5 to 5 feet/second. Coke at a temperature above the coking temperature, for example, at a temperature from about 100° F. to about 400° F., preferably from about 1500 to about 350° F., and more preferably from about 1500 to 250° F., in excess of the actual operating temperature of the coking zone is admitted to reactor 1 by line 17 from heater 2 in an amount sufficient to maintain the coking temperature in the range of about 850° F. (454° C.) to about 1200° F. (650° C.). The pressure in the coking zone is maintained in the range of about 0 to 150 psig, preferably in the range of about 5 to 45 psig. The lower portion of the coking reactor serves as a stripping zone S in which occluded hydrocarbons are removed from the coke by use of a stripping agent, such as steam, as the coke particles move through the stripping zone. A stream of stripped coke is withdrawn from the stripping zone via line 18 and conducted to heater 2. Conversion products of the coking zone are passed through cyclone 20 where entrained solids are removed and returned to coking zone 12 via dipleg 22. The resulting vapors exit cyclone 20 via line 24, and pass into a scrubber 25 mounted at the top of the coking reactor 1. If desired, a stream of heavy materials condensed in the scrubber may be recycled to the coking reactor via line 26. Coker conversion products are removed from scrubber 25 via line 28 for fractionation in a conventional manner. In heater 2, stripped coke from coking reactor 1 (cold coke) is introduced via line 18 into a fluidized bed of hot coke having an upper level indicated at 30. The bed is heated by passing a fuel gas into the heater via line 32. The gaseous effluent of the heater, including entrained solids, passes through a cyclone which may be a first cyclone 34 and a second cyclone 36 wherein the separation of the larger entrained solids occur. The separated larger solids are returned to the heater via cyclone diplegs 38. The heated gaseous effluent that contains entrained solids is removed from heater 2 via line 40. Excess coke can be removed form heater 2 via line 42. A portion of hot coke is removed from the fluidized bed in heater 2 and recycled to coking reactor 1 via line 17 to supply heat to the coking zone.
The basic material can be introduced into the fluid coking process unit of the present invention at any one or more locations represented by B in the figure. For example, it can be introduced into one or both of lines 10 and 26. It can also be introduced independent of the feedstock directly into the coking zone 12, or into line 18 and carried to the heater then to the coking zone via line 17, or it can be introduced into recycle coke line 17. It is preferred that the basic material be introduced independent of the feedstock directly into the coking zone.
It is to be understood that the fluid coking process unit of the present invention can also include a gasifier (not shown) wherein a portion of the solids is removed from the heater and passed to a gasifier that is operated at temperatures from about 1600° F. to about 2000° F. at a pressure ranging from about 0 to 150 psig, preferably at a pressure ranging from about 25 to about 45 psig. Steam and a molecular oxygen-containing gas, such as air, commercial oxygen, or air enriched with oxygen is used to fluidize the solids in the gasifier. The reaction of the coke particles in the gasification zone with the steam and the oxygen-containing gas produces a hydrogen and carbon monoxide-containing fuel gas. The gasified product gas, which may further contain some entrained solids, is removed overhead from the gasifier and introduced into heater to provide a portion of the required heat as previously described. U.S. Pat. No. 5,284,574 which is incorporated herein by reference discloses a fluidized process unit having a coker, a heater and a gasifier.
Having thus described the present invention, and a preferred and most preferred embodiment thereof, it is believed that the same will become even more apparent by reference to the following examples. It will be appreciated, however, that the examples are presented for illustrative purposes and should not be construed as limiting the invention.
The following examples are presented for illustrative purposes and are not to be taken a limiting in any way.
All of the following examples were performed using an open system pyrolysis unit coupled with a mass spectrometer to measure the rate of methane (mass 16) evolution from pyrolysis of the resid samples with and without the basic alkali or alkaline-earth-containing additive. The pyrolysis unit, referred to herein as the Temperature-Programmed Decomposition (TPD) unit is substantially the same as that described in Fuel, 1993, 72, 646. A fixed linear heating rate of 0.23° C. per second was employed in all experiments.
A 52 kcal/mol kinetic process to produce methane is associated primarily with the cracking of alkyl side chains (>Cl) of resid. Kinetic processes ≧54 kcal/mol are primarily associated with de-methylation reactions of aromatic cores. 23 TPD runs were conducted utilizing three different resids with and without the addition of 1000 wppm NaOH. The results of fits to the methane spectra employing a discrete distribution of activation energy at 2 kcal/mole increments and a fixed preexponential factor of 2×1013 sec−1, were pooled and analyzed using the analysis of variance (ANOVA) method coded in Statview statistical software. The results for the ≧54 kcal/mole methane evolution processes are shown in Table 1 below.
These kinetic results were used to predict the rate of methane evolution at a constant temperature of 530° C. (simulated fluid coking condition).
Calculations were made at lower temperature for resid with 1000 wppm NaOH.
This application claims benefit to the filing date of U.S. provisional application No. 60/872,172 filed Dec. 1, 2006.
| Number | Date | Country | |
|---|---|---|---|
| 60872172 | Dec 2006 | US |
