Chemical apparatus and process disinfecting – deodorizing – preser – Chemical reactor – Fluidized bed
Reexamination Certificate
2001-06-08
2004-01-20
Johnson, Jerry D. (Department: 1764)
Chemical apparatus and process disinfecting, deodorizing, preser
Chemical reactor
Fluidized bed
C422S139000, C095S112000, C095S122000, C095S149000, C095S159000, C095S162000, C096S130000, C096S144000, C096S145000, C502S020000, C502S045000
Reexamination Certificate
active
06680030
ABSTRACT:
BACKGROUND OF THE INVENTION
This invention relates to processes and apparatuses for the fluidized contacting of catalyst with hydrocarbons. More specifically, this invention relates to processes and apparatuses for stripping entrained or adsorbed hydrocarbons from catalyst particles.
DESCRIPTION OF THE PRIOR ART
A variety of processes contact finely divided particulate material with a hydrocarbon containing feed under conditions wherein a fluid maintains the particles in a fluidized condition to effect transport of the solid particles to different stages of the process. Catalyst cracking is a prime example of such a process that contacts hydrocarbons in a reaction zone with a catalyst composed of finely divided particulate material. The hydrocarbon feed fluidizes the catalyst and typically transports it in a riser as the catalyst promotes the cracking reaction. As the cracking reaction proceeds, substantial amounts of hydrocarbon, called coke, are deposited on the catalyst. A high temperature regeneration within a regeneration zone burns coke from the catalyst by contact with an oxygen-containing stream that again serves as a fluidization medium. Coke-containing catalyst, referred to herein as spent catalyst, is continually removed from the reaction zone and replaced by essentially coke-free catalyst from the regeneration zone. Fluidization of the catalyst particles by various gaseous streams allows the transport of catalyst between the reaction zone and regeneration zone. Methods for cracking hydrocarbons in a fluidized stream of catalyst, transporting catalyst between reaction and regeneration zones and combusting coke in the regenerator are well known to those skilled in the art of FCC processes. To this end, the art is replete with vessel configurations for contacting catalyst particles with feed and regeneration gas, respectively.
A majority of the hydrocarbon vapors that contact the catalyst in the reaction zone are separated from the solid particles by ballistic and/or centrifugal separation methods within the reaction zone. However, the catalyst particles employed in an FCC process have a large surface area, which is due to a great multitude of pores located in the particles. As a result, the catalytic materials retain hydrocarbons within their pores, upon the external surface of the catalyst and in the spaces between individual catalyst particles as they enter the stripping zone. Although the quantity of hydrocarbons retained on each individual catalyst particle is very small, the large amount of catalyst and the high catalyst circulation rate which is typically used in a modern FCC process results in a significant quantity of hydrocarbons being withdrawn from the reaction zone with the catalyst.
Therefore, it is common practice to remove, or strip, hydrocarbons from spent catalyst prior to passing it into the regeneration zone. Greater concentrations of hydrocarbons on the spent catalyst that enters the regenerator increase its carbon-burning load and result in hotter regenerator temperatures. Avoiding the unnecessary burning of hydrocarbons is especially important during the processing of heavy (relatively high molecular weight) feedstocks, since processing these feedstocks increases the deposition of coke on the catalyst during the reaction (in comparison to the coking rate with light feedstocks) and raises the temperature in the regeneration zone. Improved stripping permits cooler regenerator temperatures. Stripping hydrocarbons from the catalyst also allows recovery of the hydrocarbons as products.
The most common method of stripping the catalyst passes a stripping gas, usually steam, through a flowing stream of catalyst, counter-current to its direction of flow. Such steam stripping operations, with varying degrees of efficiency, remove the hydrocarbon vapors which are entrained with the catalyst and adsorbed on the catalyst. Contract of the catalyst with a stripping medium may be accomplished in a simple open vessel as demonstrated by U.S. Pat. No. 4,481,103 B1.
The efficiency of catalyst stripping is increased by using vertically spaced baffles to cascade the catalyst from side to side as it moves down a stripping apparatus and counter-currently contacts a stripping medium. Moving the catalyst horizontally increases contact between the catalyst and the stripping medium so that more hydrocarbons are removed from the catalyst. In these arrangements, the catalyst is given a labyrinthine path through a series of baffles located at different levels. Catalyst and gas contact is increased by this arrangement that leaves no open vertical path of significant cross-section through the stripping apparatus. Further examples of these stripping devices for FCC units are shown in U.S. Pat. No. 2,440,620 B1, U.S. 2,612,438 B1, U.S. 3,894,932 B1, U.S. 4,414,100 B1 and U.S. 4,364,905 B1. These references show the typical stripping vessel arrangement having a stripping vessel, a series of outer baffles in the form of frusto-conical sections that direct the catalyst inwardly onto a series of inner baffles. The inner baffles are centrally located conical or frusto-conical sections that divert the catalyst outwardly onto the outer baffles. The stripping medium enters from below the lower baffles and continues rising upwardly from the bottom of one baffle to the bottom of the next succeeding baffle. Variations in the baffles include the addition of skirts about the trailing edge of the baffle as depicted in U.S. Pat. No. 2,994,659 B1 and the use of multiple linear baffle sections at different baffle levels as demonstrated in
FIG. 3
of U.S. Pat. No. 4,500,423 B1. A variation in introducing the stripping medium is shown in U.S. Pat. No. 2,541,801 B1 where a quantity of fluidizing gas is admitted at a number of discrete locations.
Currently in stripping vessels for FCC units, the baffles are typically oriented to have an angle of 45° with respect to the horizontal. The sloped baffles assure that catalyst moves off the tray down to the next level in the stripping vessel. However, because the sloped trays each occupy substantial elevation, they limit the number of trays that can be installed in a given height of a stripping vessel. The greater the number of trays in the stripping vessel, the greater the overall performance. Moreover, sloped baffles generate a differential pressure head between holes that are lower in elevation on a baffle compared to the holes which are higher in elevation on the baffle. Because the pressure is going to be greater at lower elevations on the baffle, the velocity through the jets on the baffle will be greater at higher elevations on the baffle. This makes hydraulics through the stripping vessel more difficult to control. Moreover, erosion occurs through the jets which are higher on the baffle than through jets that are lower on the baffle because of the velocity differential. Consequently, the variously eroded holes exacerbate the difficulty in controlling hydraulics. On the other hand, setting baffles at a smaller slope will result in catalyst accumulation on top of the baffle unless fluidization over the baffle is increased, which could require increasing the flow rate of stripping medium.
It is an objective of any new stripping design to minimize the addition of stripping medium while maintaining the benefits of good catalyst stripping throughout the FCC process unit. In order to achieve good stripping of the catalyst with the resultant increased product yield and enhanced regenerator operation, relatively large amounts of stripping medium have been required. For the most common stripping medium, steam, the average requirement throughout the industry is about 2 kg of steam per 1000 kg (2 lbs. of steam per 1000 lbs.) of catalyst for catalyst stripping. In the case of steam, the costs include capital expenses and utility expenses associated with supplying the steam and removing the resulting water via downstream separation facilities. Where there is not adequate supply or treatment capacity, the costs associated with raising the addition of stripping m
Hedrick Brian W.
Koebel Jeffrey P.
Puppala Kalidas
Doroshenk Alexa A.
Johnson Jerry D.
Paschall James C.
Tolomei John G.
UOP LLC
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