SA110310847B1 - Apparatus and Process for Recovering Product from Fluid Catalytic Cracking (FCC) - Google Patents

Abstract

Abstract: The present invention provides an apparatus and a process for extracting product from catalytically converted product streams. Gaseous unstabilized naphtha obtained from an overhead receiver is compressed from an overhead receiver in a compressor. The liquid unstabilized naphtha obtained from an upper receiver and the liquid naphtha fraction obtained from the compressor were sent to a fractionation column naphtha located on top of the primary absorber. Thus, less naphtha is recycled in the gas recovery system. Figure 1.

Description

Y -— _ Apparatus and process for recovering product from fluid catalytic cracking (FCC) Full description Background of the invention Generally the invention relates to mite extraction Naphtha from a fluid catalytic reactor. The Fluid catalytic cracking (FCC) process is a catalytic hydrocarbon conversion process performed by contacting heavier hydrocarbons in the fluidized reaction zone with the particulate matter Catalytic particulate material. The reaction was carried out in the catalytic cracking process; hydrogen ‎opposed to hydrocracking; In the absence of added hydrogen, hydrogen is consumed in large quantities. As the cracking reaction proceeds, large quantities of the high carbonaceous material denoted 0 by the expression coke are deposited on the catalyst to provide spent catalyst or coke. The light vapor products were separated from the spent catalyst in the reactor vessel. The spent catalyst can be subjected to a vapor removal process using Jie inert gas to remove the hydrocarbon gases trapped from the spent catalyst. The high temperature generation process in the regenerator vessel burns the coal from the spent catalyst which can be removed. Many VO -_ products can be produced from this process; Including naphtha product and / or light product such as propylene and / any ethylene.

Fat - The gaseous Fluid catalytic cracking (FCC) products leaving the reactor section typically have a temperature between EAT and 44°C (00°F to 1701°F). The product stream is entered into the main fractionation column. The product obtained from the apse main fractionation column is heat exchanged using other streams© and pumped back to the main column at a tray higher than the aggregate pumping supply tray for cooling of the main column components. Bale A medium and low pressure stream is generated by heat exchange from the pumping cycles that occur in the main shaft. Sale The off-gases obtained from the overhead of the main fractionation column are treated in the gas recovery plant in order to extract 0 light products of Jie value as flaring gas fuel gas, liquefied petroleum gas (LPG), and debutanized naphtha. Two types of gas recovery units include a gas concentration system or a cold box system. The cold box system relies on low-temperature retail lee to separate the product. The Gas Concentrator includes adsorption units and fractionation columns to separate the overhead of the main fractionation column into Gis and other required light products. traditionally; The naphtha that is located in the overhead of the main column is processed in the treatment section and is separated into light and heavy parts at the bottom of the gas recovery section 0. The Fluid catalytic cracking unit (FCC) To produce a quantity of steam greater than the quantity M770

— $ — used; The amount of energy that is exported as steam is an economic consideration when designing an FCC unit One way to increase the net steam output of a FCC unit is to improve heat recovery from the main fractionation column column for the FCC and the gas recovery section. The heat recovered from the main gasification column is the main source of energy for the eras gas recovery sector from the total steam obtained from the FCC unit. Improved Process and Instrumentation Required to Recover Value Products from Product Gases (FCO) Improved instrumentation and process is required to recover value products from FCO with reduced energy requirements to further facilitate steam generation. 0 definitions as used in this document; The following expressions have corresponding definitions. The expression "communication " means that matter is allowed to flow practically between the various components. The expression "downstream communication" means that at least 0 part of the matter flowing into the target object in downstream communication can practically flow from the object it is connected to. The expression "upstream communication" means that at least part of the

A Q — _ the substance flowing into the target object in the kissing contact practically from the object to which it is connected. Jail' direct communication means that the flow obtained from the precomponent enters the postcomponent without undergoing a change in composition as a result of physical fractionation or chemical conversion. © means column column: a distillation column, or a column for separating one or more components of different degrees of volatility, which may have a reboiler and a condenser on its overhead, unless otherwise stated. Each column includes an overhead of the column condenser Sa and reflux a portion of an overhead stream again to the top of the column and a boiler sale] Boiling at the bottom of the column to vaporize the bottom of the column to vaporize and send part of the sediment stream back to the bottom of the column. A pre-heating process can be done for the feed streams that are entered into the columns. The top Jaz all is Ble on the vapor pressure of the upper part at the shaft outlet. The bottom temperature is the liquid bottom outlet temperature. VO when Ble x is an integer denotes a hydrocarbon stream _has hydrocarbons with [5x or a few carbon atoms, preferably x and a few carbon atoms. “Ct when ‘” is an integer denotes a hydrocarbon stream 2 with hydrocarbons with X and or more jag carbon atoms preferred X M7710

_— a" _— and more carbon atoms. 'predominant ' denotes a majority; and suitably at least 786 wt.; Preferably at least 72950 wt. The general description of the invention in a model of the process; The present invention includes a fluid catalytic cracking process comprising the introduction of a hydrocarbon stream into a fluid catalytic cracking reactor. The hydrocarbon feed is contacted ae contacted catalyst to obtain products and part of the components are entered into the main fractionation column. The upper part of the obtained products is separated 0 from the main column in the upper receiver and the liquid stream is removed from the upper receiver in a naphtha splitter column Gall to provide a light naphtha stream Gis. In another model of operation; The present invention includes a conversion and fractionation process comprising the introduction of a first hydrocarbon stream into the first reactor to contact the hydrocarbon stream with the catalyst to provide the products. Part of the products is fed into the Vill splitting naphtha Yo at the end; The light naphtha stream is sent from the naphtha splitting device to the primary absorber column 1. In another model of operation; The present invention includes a catalytic cracking and fractionation process comprising the introduction of a hydrocarbon stream A77

A _ 7 —

first stream to the reactor. The hydrocarbon feed is contacted with the hydrocarbon stream

The catalyst to provide a broken product. The eda of the broken products is entered into the hash column

main main fractionation column . The upper part of the products that have been broken have been separated

Obtained from the main column in the upper receiver. in the end; is separated

© Liquid stream obtained from the upper receiver in the splitting naphtha column

,. light naphtha stream column

In the embodiment of the apparatus the present invention includes a catalytic cracking apparatus

It includes a catalytic reactor and a main fractionation column connected to the reactor. communicate

The upper receiver with the overhead of the main fractionation column 0 and the Gaal separating column connect with the | Saud for the upper future.

In the AT embodiment of the device the present invention lee includes a converter and a fragmentation device comprising a reactor

The first catalytic reactor and the naphtha separation column in contact with the first catalytic reactor. communicate

The first absorption column with a splitting naphtha column lai}.

In another alternative embodiment the present invention includes a catalytic cracker comprising a first reactor and a main fractionation column VO in connection with the first reactor

mentioned. The upper receiver connects with the main leas splitting naphtha column

With the upper receiver -overhead receiver

Brief description of the graphics

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M - Figure 1 is a diagram of the present invention. The ¥ figure is an outline of an alternative embodiment of the present invention. Detailed description:

Gall (Jie « multiple naphtha cuts dala Laie splitting naphtha ¢ light and heavy naphtha © splitting naphtha after passing through a group of absorption and fractionation columns In the gas recovery section to increase the functions and temperatures of the reboiler boiler and the unwanted circulation of heavy material in the columns; heat exchangers and pumps «which reduces energy efficiency.The present invention aims to separate The splitting naphtha is not 0 fixed in the upper part of the overhead of the main column before it is directed to the gas extraction glad and a group of primary absorption units Yau primary absorber from the splitting naphtha after Gas recovery section Diverting heavy components of naphtha from the sale boilers into the separator column and debutanizer column reduces the energy requirements and lowers the operating temperature of the two reboilers1 on the aforementioned columns. The invention separates the unstable light gall from the heavy components in a splitting naphtha column. based on the boiling point ranges of the required naphtha scraps; The liquid produced by the intercompressor obtained from the main splitting naphtha top gas compressors of the splitter can also be directed to the naphtha separation column M770

And -

column. The upper gas obtained from the Gal separator column) consisting of light naphtha and light components is condensed and sent to the primary adsorption unit. Subsequently; Light naphtha is only recycled in the gas concentration sector. The precipitate product obtained from Lie splitting naphtha is heavy naphtha and can be separated into two or more chops if required on the basis of properties required in one or more naphtha separators which can be One or more columns with walls

Comma or traditional hash columns. The present invention is an apparatus and a process that can be described with reference to the six components shown in Figure 1; a catalytic reactor 1st, a regeneration vessel Te, product fractionation 01st 0, and a gas recovery strip 071 gas recovery section, optional second catalytic reactor 001 and optional second fragmentation section 0?7. Several variations of the present invention are possible; But specific models are presented in this document as an example. All other possible embodiments for the procedure of the present invention are within the scope of the present invention. For example; If You 01 first and second reactors are not Fluid reactors

catalytic cracking (FCC) 0 » Regeneration vessel 660 can be optional. The conventional FOC feedstock and high temperature hydrocarbon feedstock is the first suitable feedstock to the first FCC reactor. The common feedstock bale is Sle ayy vacuum “vacuum gas oil (VGO)” of which bale is a hydrocarbon having a boiling range from 47 C to #07 C Ton) to 0176 Q) It is prepared by M77

F.1 - A low-pressure fractionation process from the residue resulting from atmospheric pressure. The aforementioned part is low in terms of coke-producing materials and in terms of heavy metal contamination, which works to contaminate the catalyst. It includes all heavy hydrocarbon feedstocks. The invention can be applied to these materials. heavy deposits obtained from crude oil; heavy bitumen crude oil; baby oil Shale oil; tar sand extract ¢ and deasphalted residue and products obtained from Alu coal liquefaction; Atmospheric and vacuum reduced crudes. The heavy feedstocks of the present invention also include mixtures of the previously mentioned hydrocarbons, and the following list is not exhaustive. Furthermore it; Additional amounts of feed stream can also be entered after the initial entry point. Preheating of the primary feed can be carried out in tube 4 in the wash column 1 Lad is described later in this document. The 01 first reactor can be a Fluid catalytic cracking (FCC) 0 reactor or a catalytic reactor which includes the riser of the 11 first reactor and the first reactor vessel. The (sale) regenerator VE catalyst pipe delivers the regenerated catalyst from the 01 regenerator vessel at a rate set by a control valve to the VY first reactor riser through the regenerator inlet regenerated catalyst inlet . The spent catalyst tube is M7

E 11 = -

The optional spent catalyst pipe 1© delivers the spent catalyst from the YA disengaging vessel at a rate controlled by the control valve to the VY reactor riser through the spent catalyst inlet. The fluid medium Jie the steam generated by the VA distributor induces the regenerative catalyst stream upwards ©. Through the ascending pipe of the first reactor riser 17 first reactor riser samy distributes the feed stream YY in the pre-connection upstream communication with the upstream of reactor 11 on first hydrocarbon feedstream injection eh preferably using an inert atomizing gas such as steam; Through the flowing vapor of the catalyst particles to distribute the hydrocarbon Aull stream to the ascending tube of the first reactor 1. The heavy hydrocarbon feed stream is fractured to produce light gaseous pre-cracked products during coke conversion and the coke-producing material is deposited on catalyst particles to produce

spent catalyst. The 01 first reactor vessel is subsequently connected to the first 17 Ve ae ball tube. The resulting mixture of gaseous product hydrocarbons and spent catalyst advances upwards through the first reactor riser 11 and is received into the first reactor vessel 00 where the spent catalyst and gaseous product are separated. A pair of disengaging arms 4 7 tangentially or horizontally may discharge the gas and catalyst mixture from the top of the riser tube of first reactor 11 through one or more outlet points YU (only one 0 is shown ) in the YA disengaging vessel, which affects the partial separation of yao gases

- 10 - About the catalyst. The transport conduit carries hydrocarbon vapors including stripped hydrocarbons, stripping media, and a retained catalyst to one or more cyclone streams. from YY cyclones in the first reaction vessel 01 that separates the catalyst did from

© Hydrocarbon Gaseous Product Stream. The YA disengaging vessel is partially housed in the first reactor vessel, Yo, and can be considered as part of the first reactor vessel.

0.00 The gas streams deliver the hydrocarbon gaseous streams separated from the cyclone separators

TY to the assembly blower ventilator 77 in the first reactor vessel Yo to pass into the product pipe

AA through the outlet nozzle and eventually to product fractionation segment 90 for product extraction. get up

0 tubing vessel by draining the catalyst from the cyclones YY streams from cyclones to the bottom layer in the first reactor vessel (ALY) the end The catalyst including adsorbed or retained hydrocarbons can pass from the bottom layer which is in the optional separation section; ; Ports specified in the YA separating vessel wall The catalyst which has been separated in the YA separating vessel can pass directly into the optional separating section; through the layer; the fluidizing dispensing unit

0 distributor 0 Bale ¢ delivers inert fluidizing gas vapor

To the stripping section 5 5

The separation sector includes ;; OF baffles or other equipment to enhance contact between the separation gas and the catalyst.

The separated catalyst leaves the separation sector 4; For the separation vessel, YA disengaging vessel, for the first reactor vessel, 01 first reactor vessel, where the concentration of retained hydrocarbons is reduced 0, 0 absorbed, Ake by the concentration of hydrocarbons at entry or when not subjected to a separation process. Leave

view yy -

The first part of the spent catalyst; preferably the catalyst that has been separated; The disengaging vessel YA vessel of the first reactor vessel 01 through the spent catalyst stream 0 passes into the regenerator vessel 01 at a rate controlled by a slide valve. The regeneration unit 110 is subsequently connected to the first reactor .01 and a second portion of the spent catalyst in the (sale) circulation stream 07 is circulated back to the base of the VY riser at a rate controlled by a slide valve for regeneration. Contact with the feed stream without yielding

for the renewal process. 1 can work for the first reactor riser | for the first VY at any suitable temperature; Sale operates at a temperature range from Nou C to 5080 C; preferably ©0101 to 08000 m at the riser outlet 4 7. In one embodiment a higher riser temperature may be required; so that there is not less than 010 m at the outlet of the riser tube Ye and the pressure ranges from 14 to 17© kPa (in meter) (01 to VO psi) and usually less than YVO kPa ( by the meter (£4 psi). sind) can reach oil; On the basis of catalyst weight and feed stream hydrocarbons entering the bottom Ve of the riser tube; to oO Ye and usually ranges from 4:Ves)© and can range from 7:1 to ©7:sale 1. No hydrogen is added to the ascending tube. The steam may be passed in the ascending tube of the first reactor riser VY and the first reactor vessel 01 vessel equivalent to 7-72 wt. of the feed stream. Bale steam rate can be between y and 27 wt for maximum naphtha production and 10 to 11 7 wt for maximum production of 00 light olefin and average residence time in the riser can be Jill from

and 71

1 - © Thawani. The catalyst in the 01 first reactor can be a single catalyst or a mixture of different catalysts. dale The catalyst includes two components or catalysts; Any first component or catalyst and a second component or catalyst. The catalyst mentioned in US Patent No. 6 © No. 73177 82 is disclosed. In general; The first component can include any of the well-known catalysts used in the FOC field such as an active amorphous clay type catalyst and/or a high potency clay; and a crystalline molecular sieve. Zeolite species can be used as molecular sieves in Fluid catalytic cracking (FCC) processes, preferably; The first component includes large-pore zeolite; such as Y-type zeolite and active alumina; binder; It includes alumina sl silica » or an inert filler 0 kaolin Jw. stereotypically The zeolite molecular sieve suitable for the first component has a large average pore size. Gale Molecular sieves with large pores consist of plas with openings greater than BU GY meters in the specified actual diameter Lad more than OY sales 01 and rings. Pore size indices for large pores can be greater than FY Suitable large size zeolite components can include synthetic zeolite (© Jie) zeolite compounds 1 and 7; Mordinette; and fugasit. It could be for the first component; such as zeolite; Any appropriate amount of rare earth metal and rare earth metal oxide. The second component can include a medium or small pore zeolite catalyst; MFI zeolite fie as represented by at least one of the ZSM-5 » and 2514-11 ZSM-3¢ ZSM-235¢ ZSM-125¢ M770

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; 5 ZSM-485¢ ZSM-38 and other similar materials. Other suitable medium or small pore zeolite compounds include ferrierite ; erionites ¢ and preferably.; The second component shall have a medium or small pore zeolite dispersed on the layer consisting of a binder such as silica or alumina and an inert filler kaolin Jie. The second component may also include some other active materials such as beta zeolite. Said compositions may have a crystalline zeolite content of 01 to 0 75 by weight or more.” and a layer material content ranging from 0 to 0 Vo by weight. Components containing 0 74 by weight of crystalline zeolite are preferred; Components with a large amount of crystalline zeolite content may be used. generally; A medium or small pore zeolite is characterized by having an effective pore opening diameter of less than or equal to 1.7 nm Ye and 10 rings or less.” and a pore size modulus less than TY and (Jamie) form the second catalyst component is an MFI zeolite having a silicon to aluminum ratio greater than V0 and preferably more than

5. In one embodiment the ratio of silicon to Nive JY Vo aluminum can include the total amount of catalyst mixture in the first reactor over the range from 1 to yo by weight of the second component ; One that includes medium to small pore 0 crystalline zeolite compounds having more than or equal to ZY by weight of the second component is preferred. when the second component contains 0 7 wt. of crystalline zeolite with a balance of binder; inert filler; kaolin Jie” and an optional alumina active ingredient the catalyst mixture may comprise 0; to 701 wt medium to small pore crystalline zeolite preferably having a content of at least 7.8 wt. The first component 0 may include a balanced amount of the catalyst composition. in some preferred models; The proportions may not vary

P 770

11 - - The proportionality of the first and second components in the mixture is greatly increased in the first reactor. asl Forms » The second component may be zeolite 2534-5 and the catalyst mixture may include 1,4 to 01 / wt of zeolite © 28245 excluding any other component such as binder and/or or filler material. The catalyst regenerator vessel 010 regenerator vessel is subsequently connected to the first reactor vessel 01.01 reactor vessel in le reactor regeneration vessel le and coke are combusted from the spent catalyst part which is connected to a regeneration vessel The catalyst 01 regenerator vessel is in contact with an oxygen-containing gas such as air to provide a regenerative catalyst. The 01 regenerator vessel may be of the regenerator burner type as shown in Figure 1 and other regenerator vessels and other flow conditions may be suitable of the present invention. The spent catalyst stream of introduces the spent catalyst into the first or lower chamber 7+ defined by the outer wall through the spent catalyst inlet. fale The spent catalyst obtained from the 51 first reactor vessel comprises 0 carbon in an amount ranging from 1.7 to ZY by weight; Which is found in the form of charcoal. Although coke is primarily composed of carbon, it can contain anywhere from ? to 11 #7 by weight of hydrogen plus sulfur and other materials. The combustion gas comprising “oxygen ¢” enters the lower chamber 17 of the catalyst regenerator vessel 01 through the duct and is distributed by the distributor 14. As soon as Ye gas enters The lower chamber combustion (UY) is in contact with the spent catalyst which is obtained from

11 - The spent catalyst stream 08 serves to lift the catalyst with a surface velocity of combustion gas in the lower chamber TY of 1.1 m/sec (7.0 sq ft) under fast fluid flow conditions. In one embodiment the BUSTY bottom chamber can have a catalyst ranging from 48 to 371 kg/Ta (© to 0 lb/cu ft) and a surface velocity of 11 to 7.7 m/s (7 ,5 to 7 ft/sec). © The oxygen in the combustion gas comes into contact with the spent catalyst and combustion of the carbon precipitates obtained from the catalyst to at least partially regenerate the catalyst and fuel gas The mixture of catalyst and combustion gas rises into the lower chamber 17 Through the ellipse-conical transition section 16 (Jad) the TA riser section of the lower chamber 0 AY the TA riser section identifies the tube which is preferably cylindrical or extended favored upwards from the lower chamber UY the catalyst and gas mixture travels with a high gas surface velocity compared to the velocity of travel in the lower chamber TY The increase in gas velocity is due to the lower cross sectional area of the ascending section TA relative to the cross sectional area of the lower chamber which is below the section The frustoconical transition section 0-17 Hence, the YY surface gas velocity can exceed V m/sec (feet/sec). The TA riser section may have a catalyst density of less than 80 kg/m' (0 lb/sq ft). The catalyst particle and fuel gas mixture is discharged from the top of the riser tube segment 18 into the Ve upper chamber mainly; The catalyst can come out

1 - - completely renewed from the upper part of the transition section; and the VA riser section, and systems in which the regenerative catalyst partially exits from the lower chamber TY are expected. A drain is performed through a YY separator which separates most of the regenerative catalyst from the fuel gas in one embodiment; The flowing gas catalyst affects the TA riser section on the upper part of the oval cover of the VY separator and reverse flow. After that, the catalyst and gas come out heading down the discharge outlets of the separator “No. The sudden loss of torque and the downward flow causes most of the catalyst quantity JE to fall in order to condense the catalyst layer and light fuel gas, and a small part of the catalyst remains trapped in it to rise upwards in the upper chamber 0 7. The VO streams from cyclones 0 1la also separate the catalyst from the upwelling gas and precipitate the catalyst through to obtain a dense catalyst bed. Fuel gas exits from The VT Vo vortices pass through the gas stream and collect in the AY ventilator to reach the outlet dash of the catalyst regenerator vessel 0 and possibly to the flare gas or power recovery system (not shown). Catalyst density rates in the dense catalyst bed are maintained in the range from 140 to 680 kg/0m" (40:1:4 lb/pad m"). Liquefaction streams deliver a liquefaction gas, usually air, to The dense catalyst bed VE through a fluidized distributing device.In one embodiment to enhance the combustion of coke and coke in the lower chamber 217 the hot regenerative catalyst obtained from the dense catalyst bed can be recycled in the upper chamber Ve to the lower chamber through the recirculation ducts (not shown). and 71

- 1 dale A 0400 regenerator vessel can require kg of air for each kg of coal removed to obtain a complete Adee regeneration. When more catalyst is regenerated a large amount of the feed stream can be treated in the Sale first reactor. The temperature of the catalyst regeneration vessel, Te, is between 844 and 4 0 C (11 to 10 '07 F) in the lower chamber. TY and ranges from TER to 2060 m (000 Yer) q) in the upper chamber 0 and the regenerative catalyst tube is subsequently connected with the catalyst regeneration vessel Te and the regenerative catalyst obtained from the dense catalyst bed is transported from Through the VE tubes from the catalyst regeneration vessel 010 back to the ascending tube in the 11 first reactor through the Cus control valve they again come into contact with the first feed stream in tube A FCC As the process continues Ve 01 lly cleared from the first reactor AA The products broken in the tube and comprising the separating fluid exit the first reaction vessel proportional catalyst particles of catalyst particles through outlet nozzle. The products which are first crushed in tube can be subjected to 88 to 00

AN additional processing to remove microcatalyst particles or to prepare the stream before fractionation. The pipe conveys the stream of products that were first cracked to the product fractionation sector 0 and in a model that can Ve gas and the gas recovery sector 001 main fractionation column includes the main fractionation column from the fractionation column Ble 001 main column and the column is The main VY + recovery section has trays and/or cans positioned along its height to contact vapor and liquid and achieve balanced ratios at tray conditions and a set of pumping cycles to cool the main column content. It is and can be operated when the first reactor is compressed. The main fractionation column is connected later with the first reactor 0 m7720

Cov. o

It ranges from Ve to 177 kPa (in meter) (to yo psi) and bottom temperature TET to (to a TAS to 1500 F). In the product recovery segment ode the gaseous Fluid catalytic cracking (FCC) product in tube AA is directed to the bottom section of the .001 main fractionation column. column in this case; The main column 001 extracts the top stream from light products comprising unstable naphtha and light gases into the top tube 4. The top stream in the top tube is condensed into a condenser and can be cooled in a cooler both of which are represented by the number 97 before entering receiver 948 in contact Subsequent with first reactor 0. Tube 07 draws in the light off-gas stream of liquefied petroleum gas (LPG) 0 and dry gas obtained from receiver 98. The water stream is removed from the part The lower parts of the receiver 48. The liquid streams from the lower parts of the unstable naphtha leave the receiver 18 through tube 4 01 Jol part of the liquid stream from the lower parts is directed back to the overhead of the main column and the part can be directed The second in the tube 0 to the tunnel separation column 081 splitting naphtha column connected later with the section 0 gas recovery Ye gas recovery section the tube 011 can be inserted into the recovery section

Gas AY Several other parts can be separated and taken from the main column 0n which includes an optional heavy naphtha stream in tube Vo A, light circulating oil (LOO) in tube 0011 and a heavy cycle oil stream ( HCO) in tube IVY and heavy slurry oil obtained from tube 0 1140 . Portions can be extracted from any of all tubes 11-018 while the remaining portions are cooled

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“vy” and pumped back to maintain the main shaft 001 to cool the main shaft at the high entry position. The light unstable naphtha fraction has an initial boiling point (IBP) less than 05 i.e. a Jil range of 78°C (90) and a termination point (BP) at a temperature greater than or equal to 1717°C XT) is determined Boiling points for these parts using a procedure known as ASTM 82-086. © and the optional heavy naphtha fraction 198 is at or above 7171°C (7710°F) and has a BP at a temperature greater than 100°C; Preferably between 704 and 17 m (400 (GET) specifically at 707 m (470 V). A current of 1.00 137 is less than a range of 65 i.e. less than Yo m (a°) if no Presence of Vids picking or at EP in the range Te “m to e Vy (q to » + lv) and preferably TAA m (+00 q). The IBP HCO stream has a temperature EP for a stream of 0 160 and with in the range of 1270°C to 477°C (700 to Ave F), preferably 14°C Vo (V) and a heavy oil slurry stream of TBP having a temperature of 58°C for a stream HOO and includes anything whose boiling point is at a high temperature.In the gas recovery section 061 gas recovery section a splitting dill 10890 naphtha column is placed on top of the 001 primary absorber column 0 to improve Efficiency of the gas recovery plant The said model has the advantage of reducing the molecular weight of naphtha that is introduced into the 071 gas recovery section Thus the scarce gas obtained from the lower part of the primary absorption unit reduces the temperature of the boiler ale) boiling, which facilitates more efficient heat recovery. Gas recovery sector 171 is shown to be an absorption based system; Any other fluid recovery system can also be used including the cold box system. and 77

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To obtain sufficient separation of the light gas components the gas stream is compressed in tube 017 in a NYY compressor also known as a “wet gas compressor” which is subsequently connected to the upper receiver of the main fractionating shaft AA Any number of compressor stages can be used; But fale is using a double-stage compression process; The compressed fluid obtained from is cooled

© Compressor 177 and enters the future of Intercompressor; VY connected later with the compressor TY flows the liquid in the tube 1176 which is obtained from the lower part of the compressor receiver

4 and the unstable naphtha in tube 011 obtained from the receiver

upper part of the main fractionation column 1/8 in the splitting unit 081 naphtha which connects later with the YE receiver and by sending the liquid from

0 interreceptor; 11 to the YA naphtha separation column. splitting naphtha column and allowing extraction of heavy components that may remain in the wet gas exiting from the main fractionation column in tube 011 in addition to maintaining the same ranges

Boiling point for naphtha scraps. in one of the models; These streams can flow with naphtha to

YAS splitting naphtha Gil separation device. In the pattern shown in Fig. 1, the tube is flowing

11 0 to the VAY naphtha separator at high sya is high compared to tube V0 and the naphtha separator 181 is also in later connection with the lower part of the upper receiver of the main fractionating column 48 and the first reactor .01 15: 88 reactor in an embodiment; The naphtha separator is VAL

In direct post contact with the lower portion of the AA upper receiver of the main retail shaft 001 and/or

The lower part of the IVE compressor receiver enters the gas obtained from the receiver

AF second compressor YY from the top of the compressor receiver 178 upper in tube 0

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SR aka Wet Gas Compressor In subsequent connection with the NYE compressor receiver Compressor flow obtained from the second compressor 11 in tube 111 is combined with streams in the tubes VEY 5 VFA and cooled and fed into the compressor receiver The second 137 in post-break with the second compressor 0 . Compressed gas obtained from the upper © of the second compressor receiver SITY passes the tube; 17 to enter the primary absorption unit 0418 at a point lower than the entry point of the upper stream of the splitting naphtha apparatus tube 7. The primary absorption unit 0610 is subsequently connected to the upper part of the second compressor ry the liquid stream is transmitted from from the second compressor receiver 171 in the AVES tube separator shaft 7?1. The first compression stage compresses gaseous fluids to a pressure of 5;? to VTE 0 kPa (meter) (50 to 1500 psi) and preferably EAT to 190 kPa (meter) (70 to 100 psi). The second compression stage compresses the gaseous fluids to a Ly pressure of between IY EY and 7018 kPa (in meters (700 AIA) psi). The 080 splitting naphtha column can separate splitting naphtha 0 into lower portions of heavy naphtha; usually Cpr ; In pipe VAY which can be recovered in pipe 184 with the control valve on it open and the control valve on pipe 785 in the closed position or further processed in the YAO pipe with the control valve open on it and valve Closed control on pipe AE The overhead stream obtained from the splitting naphtha device VAL 0 can carry the light naphtha in the pipe bale (VAY material ©; to the pre-absorption column M770

Above - 0000 primary absorber column. Subsequently; The light naphtha Vial is only circulated in the VY gas recovery section and the upper Lill can be combined into the tube 04 exiting the dehydrogenation column Column : 06010080126 7*0 with the compressed gas stream in tube; 17 to enter the 01 primary absorber column which connects Gy© with the VA splitting naphtha column The naphtha splitting column 0 can be operated at upper pressure to keep the upper part in liquid phase; That is 7174 vee kPa (in metres) 1 (5 to 150 psi) and a temperature of 738 to 1151 C (Yo) to 5 F). In the model AT ¢ the lower parts stream obtained from the splitting naphtha 0 device in the tube YAO can be diverted through the control valve opened on it to the second splitting naphtha column 6 ). The second naphtha separation column may include a YAY partition wall placed between the feedstream inlet and the product mid-pick outlet in tube 797. The separation walls have upper and lower ends diverging from the corresponding upper and lower ends of the second naphtha separation column 17900 so that the fluid can flow over And below the walls 1 separator YAY from aad sides to opposite side. The splitting naphtha device can provide an upper product of middle in-tube naphtha (YA) and an aromatic-rich naphtha product through the outlet of the intermediate product in the in-tube 717 Villy Heavy in the in-tube downstream product / 79. The second naphtha separation column 0 can be used in any of the embodiments presented in the present document.

ve - - the gaseous hydrocarbon streams in the tubes VTE and 15 that were evacuated to the primary absorber column 001 primary absorber column were contacted with the naphtha obtained from the upper stream of the splitting naphtha device in the tube VAY to perform the separation of +0 Cos hydrocarbons by adsorption of heavy hydrocarbons in the naphtha stream on the counterstream contact oo. The debutane naphtha stream in tube VIA obtained from the 01 debutanizer column is connected to adsorption column 1 for Ollie 006 at a temperature elevated compared to the upper stream of the naphtha separator in tube VAY to perform Another separation process for +,0 hydrocarbons from © hydrocarbons. The pre-absorption column 01 does not use any condenser or reboiler but can have one or more ST pump cycles to cool the materials in the 0 column. The pre-absorption column can be operated at an upper pressure of 0.014 to VA kPa (metered) (0 to 000 psi) and a lower temperature of 0 to <An to 001 F). The prevailing liquid +,0 stream with some amounts of “b” in solution is returned in the VEY tube from the bottom materials of the primary absorber column to the tube 131 above the condenser to be cooled and returned to the second receiver AFY Ne The draining gas stream 148 is directed from the upper part of the primary absorber column 01 to the lower end of the secondary sponge absorber column VO and the circulating current 100 in tube Vo which is diverted from tube 011 By adsorbing most of the remaining Cpr and some of the ©-:0 into the gas stream discharged into the VEA tube by contacting 0 in the opposite stream. Then return the 100 obtained from the lower part of the M77 column

A - Secondary absorption in the Cpr-rich oT tube compared to the circulating current in the VOY tube by the tube 151 to the main column 0 through the pumping cycle of the tube 011. The secondary absorption column can be operated Vo. at upper pressure Jil than the pressure of the 001 primary absorber column ranges from 968 to 70090 kPa (in meter)

001 (to 33°C TA to 190 psi) and a bottom temp of 140 (0 including 101°F gas). The upper stream of the secondary adsorption unit 001 is removed to in hydrogen and hydrogen sulfide, dry amines from the prevailing hydrocarbons © using 0 hydrogen and ethylene to separate again to extract Lee and 158 can be processed Pipe to column 14 In pipe 17 the liquid is sent from the lower part to the receiver of the second compressor

0 chapter N61 and most of the Ca material is separated from 6-6, and removed in the upper stream of the separation column

Slide Lee's tube 11 through the upper VTA tube without undergoing condensation at first. The upper gas is returned to the VTA from the separation column containing the © material; liquefied petroleum gas (LPG) and some light naphtha to tube 111 without first undergoing condensation. The condenser in tube 131 partially condenses the upper current

171 and subject to each of the gas compressor discharges in the tube WA obtained from the tube 0

With bottom material stream VEY obtained from primary absorption column

01 absorber column to separate the vapor from the liquid in the receiver of the second compressor, TY

The separating column £1 V is subsequently connected to the 01 first reactor and the lower part to a receiver

2nd compressor YY and lower part saa) primary suction 11 and upper stream of naphtha A

Yo The separator can be operated at a pressure greater than the compressor inlay pressure 11 at a pressure of 7 and

L - from 13745 to 5 kPa (in meter) 000 (to 771 psi) and a temperature range of 78 to 001 VED to 7000 F). The bottom material product of the separating column in tube 167 is rich in heavy naphtha. Figure 1 shows that the liquid substrate stream can be sent from separation column 1476 to the © butane removal column Ye JY! debutanizer column through tube 117. The butane removal column 0 is subsequently connected with the first reactor 01, the lower part of the second compressor receiver VY, the lower part of the primary adsorption unit 100, and the upper part of the naphtha splitting device 1180 naphtha The butane removal column 061 can fractionate a portion of the first cracked products obtained from the initial reactor to provide an upstream of Ci and a downstream of Cot0 . gia can be separated from bottom debutane material in tube 1176 between tube VTA to carry debutanized naphtha to preseparator column 05418 to aid absorption of Cot material and VY tube contents using each of open control valves on it; which can serve to recycle the de-butane naphtha to a separator (VA Lal) and optionally in combination with tube .016 if required; Salem Vo from de-butane naphtha downstream products can be sucked into VY tube using control valve 01001H”_ open on it and closed post-control valve on tube 177 as product or further separated into two or more droplets based on desired properties In one or more naphtha separators (not shown) which can be columns with separation walls or one or more conventional fractionation columns. usually; The Yo to 50 7 wt debutane Yo naphtha 060018012860 is recycled back to PSU 0660 at M777

M7 - Pipe 118 to control the extraction of light hydrocarbons. The debutanizer column can be operated at a top pressure of 0174 to 1774 kPa (You vo (psi) and a bottom temperature of 6907°C to 4007°C (00? to 40 F). The pressure shall be kept as low as possible to keep the boiling boiler temperature© as low as possible while allowing complete condensation using atypical refrigerants without the need for freezing. The upstream in tube 164 obtained from the butane stripper contains an olefinic product RH which can be sent to a liquefied petroleum gas (LPG) separating column which subsequently connects with the top stream of the stripbutane ATs In separating column 171 (LPG) the material,©, can be sent from the upper stream in tube 174 to the 0 separator p to extract the -propylene product, material b© can be extracted from the lower part in tube 177 for mixing in Gasoline pool as a product or for further processing. The 171 LPG separator can be operated using an upper pressure of 194 to 007 kPa (in meters) (01 to yo psi) and a bottom temperature of 78 to 1717 C (001 to ( Yor In an embodiment; the material ben in tube 11177 can be delivered as a hydrocarbon 0 iso: second hydrocarbon stream to the second catalytic reactor 001 which is subsequently connected to the upstream of the main fractionating column 001 main fractionation column and bottom of primary absorption unit 01410 and bottom of VV liquefied petroleum gas (LPG) separator in one embodiment;© stream in tube 1177 can be evaporated in evaporator 188 from which tal exits vaporized in tube 0918 and lead is ultravioletized before being introduced into the second catalytic reactor M700

vq — ~ . The second catalytic reactor 701 is subsequently connected to the IAA evaporator unit in embodiment; The light naphtha stream may be drawn from the butane stripper side 001 as a VAY side cutin line The side cut can be taken from the vapor side intake area to avoid evaporation of the liquid stream in the vaporizing unit. The side cut of the naphtha in the pipe VAT can be mixed with the evaporated © stream in the pipe 1910 to provide a second hydrocarbon feed stream in the pipe 119, so that the second reactor 001 second reactor is connected later with the debutanizer column The first, 001, through the side steam intake area. The 191 line heat exchanger can perform superheating of the vaporized hydrocarbon stream. The lateral vapor intake area of VAY 0 shall be half as low as that of the first butane removal column 01 and less than the inlet of the feedstream of AY The second catalytic reactor 0 can be a reactor Fluid catalytic cracking (FCC) ou . Although the 0001 second reactor is depicted as an ol reactor (FCC) it must be recognized that any suitable catalytic reactor may be used; Such as fixed bed Vo reactor or fluidized bed reactor. The second hydrocarbon stream may be introduced to the second 001 reactor in the recycle stream tube 198 through the feed stream distribution unit .707 and the second feed stream may consist of at least Sia form of Cio hydrocarbons ; Preferably, it consists of olefins, © to: ©. The second hydrocarbon stream predominantly includes hydrocarbons with 01 or fewer carbon atoms and preferably between 4; None of the 0 carbon atoms. Preferably, the second hydrocarbon feed is a portion of the dead products

A: ARS — first cracked in 01 first reactor which is fractionated in 01 main column of product recovery section 0 which is supplied in 01 second reactor in an embodiment.” The second reactor is later connected to the product fraction and/or the first reactor 01 is previously connected to the product fraction A© The second reactor 001 second reactor can include a riser tube in the second reactor VY is The second hydrocarbon feed stream is contacted with the catalyst which is connected to the second reactor 0 by means of the sale tube, the catalyst 04 catalyst return pipe previously connected to the ascending tube of the YY AU first reactor riser to produce improved products that have been cracked. The catalyst can be fluidized by an inert such as steam obtained from a YoU distributor 0 in general; The second reactor 0 can be operated under specified conditions to convert the light naphtha feedstream into minor hydrocarbon products. CoCr olefins break down into one or more light olefins; Such as ethylene and/or propylene. The second reactor vessel is subsequently connected to the first reactor riser 70 to receive the improved products and catalyst from the first reactor riser. The gaseous mixture is directed; The improved product 0 of the carbonate and the catalyst goes up through the ascending tube of the first reactor riser 117 and is received into the vessel of the second reactor YY second reactor where the catalyst, gaseous hydrocarbons and improved products are separated. A pair of discharge arms 308 tangentially or horizontally may discharge Lala gas and catalyst from the upper uptube of the YOY second reactor through one or more outlet holes 0? (Only one is shown) in the vessel of the second reactor, Ye 001 second reactor, which achieves partial separation of gases from the catalyst. M 770 can fall

vy - - catalyst for condensation of the catalyst bed in the second reactor vessel .771 . cyclones streams from cyclones 4 77 in the second reactor vessel 0 can separate the catalyst from the second cracking products. After that, the hydrocarbon products that have been cracked can be removed from the second reactor 701 through outlet 1 which is later connected with the ascending tube of the first reactor riser © the second reactor YY through the second cracked products tube 774. Circulating the separated catalyst through the recycling catalyst tube Yet from the second reaction vessel 771 controlled by the control valve back to the ascending tube of the second reactor 7017 contacting the second hydrocarbon feed stream. In some embodiments the second reactor © may include a mixture of the first 0 and the second catalyst components as previously described for the first reactor. in one of my favorite forms; It can include the second reactor 0 less than + ZY wt; Preferably less than 75 wt of the first component and at least 07 wt of the second component. In another preferred form; The second reactor 0 may include a second dais component, preferably zeolite 2514-5 as a catalyst. The second reactor 001 is later connected to the catalyst regeneration vessel 0 regenerator vessel and also receives the regenerative catalyst out of it NO in tube 706. In one of the pala the first catalytic reactor 01 and the second catalytic reactor 001 share In the same catalyst regeneration vessel, Te, the same catalyst composition can be used in both reactors 01 and 700. However if a high percentage of small to medium pore zeolite is desired in the 0000 second reactor the replacement catalyst added to the second reactor 7010 may include a high percentage of the second catalyst component. Whereas, 0 the second catalyst component does not inactivate as rapidly as the first catalyst component; And there is no need to send m770

vy - a little bit of catalyst stock to catalyst regeneration unit 01 and an excess amount of catalyst stock can be recycled to the upstream 7117 in the return stream 704 without catalyst replenishment to maintain a high level of the second catalyst component in the second reactor 001. Tube 701 carries the spent catalyst from the second reactor vessel “YY” using control valve 00001 _ to restrict the flow rate of catalyst© from the second reactor 0 to the regenerator vessel 10. The catalyst regeneration unit is connected. Later with the second reactor 701 through the tube 716. Means for separating the catalyst compositions from the corresponding reactors can also be used in the catalyst regeneration unit 18. The riser tube of the first reactor riser of the second reactor 71" can be operated at any Suitable conditions; such as a temperature of 4125 C to 705 A preferably a temperature of 550 to Tee C and a pressure of 00 to 700 kPa (in meter); preferably a pressure of 0 to 0 kPa (meter), optimally at pressures ranging from 0010 to SEY Pa (meter).Usually, the residence time of the riser of the second reactor 701 can be less than ½ seconds, preferably between ? and seconds. Examples of riser tubes and operating conditions are disclosed in US Patent AL + YOOYV/Y uA and US 7711685097 "b. Vee products obtained from the 001 second reactor are channeled into the YYA tube To the second product recovery section Jia 01. Another aspect of the device and process is the recovery of heat from the second products in tube 174 of the second reactor 701 in the Fe wash column and the To wash column is connected later With the mentioned second reactor 701 and previously connected with the first reactor .01 first reactor Figure 1 shows;

: Cpr model; The first hydrocarbon feed stream in tube 1 carrying the first hydrocarbon stream of the first reactor 01 to come into contact in the wash column with the second product in tube 778 to preheat the first hydrocarbon stream 6 and cool the second products in tube 774. The wash column Vo is later connected with tube The first hydrocarbon feed stream 6>. The second product stream is introduced at 0 of tube 778 to the lower section of the wash column +7 and is in contact with the first hydrocarbon feed stream of tube 1 introduced to the upper section of the wash column 30 in the counter stream system preferably. The Vo wash column may include pump cycles (not shown) to increase heat recovery and not a reboiler. The second product stream includes a little LCO and 1100 proportionately and slurry oil which is adsorbed with the catalyst particles in the second products in the first hydrocarbon 0 feed stream in tube A exiting the wash column 01 in tube A and working column Washing Fe transfers heat from the second product stream to the first hydrocarbon feed stream, which cools the second product stream and heats the first hydrocarbon feed stream, and maintains heat. And through the said contact; Thus, the first hydrocarbon feed stream 11 can be heated to a range between VE to 1077 °C, and the catalyst present in the second product of the second 0 reactor is selected. The hydrocarbon feed stream comes out of the wash column 71 in Tube 8. The first reactor 01 is subsequently connected to the wash column through tube cA and the catalyst chosen can catalyze the reaction in the first reactor 01. The wash column is operated at an upper pressure ranging from 35 to 178 kPa (in meters) (2 to Ye psi) and a bottom temperature of 748 C to TET (0 58 to 0 150 F). The second cold product exits from the washing column in the NTT tube

The cooled secondary products are always condensed in the upper tube 777 in the form (Ha) and enters the receiver of the washing column 4?7. The liquid part of the second products is returned to the upper section of the washing column 01 and the steam part of the second products is directed to the third compressor Yo which is later with wash column Yo and second reactor .701 The third compressor 7460 can be single stage© or followed by one or more YEE compressors.In Alla there are two stages;as shown in Fig. OV The interfacial compressed stream is cooled and introduced to the interfacial receiver 7?7. The liquid obtained from the VEY receiver in the YOY tube is introduced to the depropanizer yoo column while the gaseous phase is introduced YET to a fourth compressor YEE and the second compressed gaseous product stream is fed into the tube YEA obtained from compressor 1;4 at 0 pressures ranging from 1774 to YOY kPa (in counter) Foo Yee (psi) to the 001 depropanizer column through the tube YoY The depropanizer column You is later connected to the .001 second reactor in the depropanizer column ( You fractionation of the compressed second product stream to provide an upper stream Cr and a bottom material stream +m© to avoid unnecessary equipment duplication and the upper stream of the Ve propane removal column is processed to carry light fractions of second products from the second reactor in the gas recovery sector ‎VY. gas recovery section holds the upper tube; 115 the upper stream of Cs materials to be inserted into a tube 174 and enter the lower sector of the absorption column 1 for the primary 1001 primary absorber column in the gas recovery sector NY and hydrocarbons: © from the upper stream © are absorbed into the naphtha stream in 001 primary absorber column This allows extraction of 0 propylene and dry gas and no need for double absorption systems or olefin separation schemes and 76

A: Yo — - light alternative. The Yoo depropanizer column operates at an upper pressure of 0 to YET kPa (00 to Fou psi) and a bottom temperature of 171 to 1777 C (You) to 7*0 f). The downstream depropane in tube 4 YO exits the bottom of the You depropanizer column and enters the second depropane column 7710 through tube 4 709. The second depropane column 0 is subsequently connected with the second reactor .000 second reactor In the second butane removal column (YT) fractionation of the propane portion of the pressurized second product stream occurs to provide an upper stream Cp and a lower portions stream of light naphtha Co. The upper tube 171 carries the top stream of the predominant ©, hydrocarbons to undergo The second No 001 debutanizer column operates at an upper pressure of 726 µPascal to 156 kPa (4lb to 100 psi) and a bottom temperature It ranges from 47 m to 7144 m (Ye) to 7000 F). The debutane bottom portions of the light naphtha stream exit into tube 7764 of the second debutane column 0 which can be further processed or sent to the gasoline pool. Vo combines the device and process flexibly to provide recycling material from the second 000 product recovery section without affecting the gas recovery section 171. if there is a dala for having a small rate of recycling sale flow to achieve the target propylene output; The evaporated Ben hydrocarbons can be diverted from the upper tube YY of the second butane removal column 7310 in tube 717 through the control valve opened on it

NE and carried to tube VT Fig. 1 shows the current at which the converted Co hydrocarbons are not sufficiently vaporized; so that it is inserted into tube 177 carrying Co hydrocarbons in the down material stream of a liquefied petroleum gas (LPG) separator unit to the YA feed stream tube it is convenient to vaporize the two streams in tubes 77676 and 7761 carrying hydrocarbons Co Sila© heat exchanger for evaporator 188. Vaporized hydrocarbons are transferred in tube 0910 and can be preheated in the heat exchanger before being introduced as part of a liquid hydrocarbon stream into the second reactor. In another embodiment of the present invention shown in Fig. of the splitting naphtha device remains above the gas recovery section as in Fig. 1; but the debutanizer column (0) is replaced ji sul is attached to the depropanizer column and the sol Las liquefied petroleum gas (LPG) separation column is dispensed to increase energy efficiency and reduce capital cost with reduced flexibility. denoted by the initial symbol (). All elements of Figure 1 are the same as those of Figure 1. Vo gas recovery segment “071” in Figure 1 differs from the model of Figure 1. basis of the boiling point ranges for the required naphtha scraps; » alternatively the interfacial compressor fluid in tube 1 ' may be routed to the separator shaft £1 in accordance with the given alternative; The liquid from the intercompressor 1 ! flows into the separating shaft VET at the inlet position at a temperature higher than the pipe temperature £4 LV otherwise; All parts of the ANT separator fluid flow

The name is VA splitting naphtha Gal, as previously described in Figure 1. The liquid bottom material stream is sent from separation column 147 to first 131 depropanizer column through tube VY. The first propane depropane column VU is subsequently connected with the 01 first reactor and fractionates a portion of the first cracked products lly obtained from the first reactor 01 to provide an upstream and downstream materials. Cpr. The upper stream in tube 164 ' obtained from the depropane column contains an olefin© product which can be sent to a propylene separator (non-Rial) which can be or is connected to the top of the depropane column depropanizer "101 column". The downstream material stream in the YT tube can be separated between tube VIA 0 to deliver depropanated naphtha to PSU 048 to assist in adsorption of Cor materials and tube VAY to re- Circulation to a 081 splitting naphtha column or product recovery in the AVY tube in one embodiment; the light feed stream may be drawn from the side of the first 011 depropanizer column ' as a side naphtha picker in The tube side cut in line Yo 870' was obtained from the feed entry point for line 7. The side cut can predominantly include hydrocarbons, ©. The side cut can be in the form of -vaporize a liquid stream in an evaporator side naphtha picker in tube 187' can provide all second hydrocarbon stream in M7

— vA-

Tube 191 or may be mixed with vapor propane side draw material in a return tube

Circulating You to provide a second hydrocarbon stream in the VAY can

The 001 second reactor is later connected to the first propane column

101 depropanizer column ' By means of the YAY steam lateral intake feed stream the 191 heat exchanger on line can superheat the feed stream

The second hydrocarbon vaporized.

in general; The operation of the second reactor is 001 second reactor connected later with stripping column

Albroyan 101 depropanizer column ; and the second product recovery section 771 recovery section 0 ' as described in Figure 1. except that the intake stream is taken

Bypass steam from the second propane stripping column You into tube You' for recirculation to the reactor

The second .701 560000 reactor in the aforementioned model » propane removal column 150 is

A second depropane column, YOu, and the debutane column, Yo, is a first debutane column

Ye first debutanizer column The sides can be 1 to the other of the mentioned model as described in Figure 1.

Example

Fluid catalytic cracking (FCC) for gas recovery section simulated

As a base with a naphtha splitter column Vial (ad) subsequent to the gas recovery sector

recovery section. Jas naphtha splitter column provides droplets of naphtha

M 7710

A va — light and heavy naphtha. An additional gas recovery sector (FCC) of the invention shown in Figure 1 is simulated in this case all light naphtha from line 17 in line 1 is taken in line 1 and all heavy naphtha is taken from pipe VAY heavy naphtha from line in tube 184. The simulations yield the same product flow rates and pickups with the same fractionation boiling points© from the base case and the inventive case. With regard to the comparison; The two SBI models are powered by the extraction of the same © and © hydrocarbons in both cases. The flow rate of the light naphtha recycling stream obtained from the bottom materials of the debutanizer column in tube 118 should be increased to the primary absorber column 1 of the inventive AW where a little bit of Unfixed naphtha 0 to ye primary absorber column the lower part of the main column receiver and the upper part of the gas compressor receiver for the basic case. The flow rate of the recycled LCO in the VOY recycled in line must be increased from the secondary absorber unit from the main column and returned to obtain the same net extraction process in the secondary absorber VO unit. The tasks are clarified preheating of separating columns; The debutanizer columns and splitting naphtha gill columns in the gas recovery sections in the base case and the inventive case are shown in Table 1. Table 1 shows a percentage reduction of 7 78 from the total heating tasks of the reheating boilers. Boil reboilers. m 7770

— $4 — Table 1 Base Case Inventive Case (Gigacal/hour) | (Gacal/h) Feed to the butane stripping unit m4 debutanizer reboiler reboiler separator Yyo,VY YY, AT Baill splitting naphtha reboiler reboiler separator YY, lo YV,vv Stripper Reboiler Y y 6 1 , ayy Debutanizer Feed Preheat

— \ ¢ — LL] serene Naphtha Splitter Feed Preheat 7 Naphtha Splitter Feed Preheat te ho for the innovative case; The splitting naphtha column reboiler has a high outlet temperature of TY m La to operate at high pressure to keep the top product in the 0 liquid phase with this said temperature being AST from The lower outlet temperatures of the debutanizer column and Ally stripper column reboilers are significantly reduced by 506 and 11 °C respectively. The temperature decreases in the innovative case As to cycle light naphtha only in the gas concentration sector. Thus, a higher Ji sha degree is needed to re-boil those columns. without having to explain again; It is believed that those skilled in the field; using the previous description; able to use the present invention with all its advantages. Hence the pre-favorite specific forms 0 are marked chil and do not limit the rest of the list in any way. previously; daria All temperatures are in degrees Celsius; All parts and proportions shall be by weight unless otherwise specified. in addition to; The control valves described are in an open or closed state, partially open to allow flow into each of the corresponding tubes. died

bd Y —_ _ from the previous description; Those skilled in the art ascertain the main properties of this invention without straying from the scope and content of the invention; They also have the ability to make many changes and modifications to the invention to adapt it to many uses and conditions. m 771

Claims (1)

List the protective elements 1-1 A catalytic cracking apparatus comprising: ¥ - catalytic reactor ¢ VF main fractionation column connected to said reactor; ; An overhead receiver connected to the overhead of the main fractionation column ~~ © mentioned; 1 splitting naphtha column Gall attached to the bottom 2 communication with 1 ““mahet_of said upper receiver; splitting naphtha Gall connected to a separation column primary absorber column sf A column of absorption A ¢ mentioned column 8 mentioned in connection with a column to remove butane splitting naphtha column The naphtha separation column is 0.debutanizer column 1) 1?- The catalytic apparatus according to claim (1), where it also includes a catalytic reactor Y connected to the absorption column 1 of the aforementioned primary absorber column. 1 ©- The catalytic apparatus according to claim (1); it also includes a Y debutanizer column connected to the absorption column 1 of the primary absorber column ¥ mentioned. vo 1 4- The catalytic apparatus according to protection element (0), where it also includes a second Y reactor connected to the aforementioned debutanizer cotumn. 1#- The catalytic apparatus according to the protection element (;); Where the aforementioned “second reactor” is connected to the vapor withdrawal side of the aforementioned debutanizer column ¥. 1 +- the catalytic apparatus according to protection element 0 (V) where the column is Separation liquefied petroleum gas (LPG) Y is connected to the top of said debutanizer column YF; the second reactor is connected to the bottom of said liquefied petroleum gas (LPG) separation column. 1 7- catalytic apparatus according to claim (1); also comprising a wet gas compressor 7 in connection with said upper receiver and a separation unit in connection with said wet gas compressor ¥; and a splitting naphtha column Gd) 4 connection to the bottom of the separator unit. = A 1 catalytic apparatus of protection element (1); also comprising a hela “for wet gas in connection with said upper receiver and a separator unit in connection with said wet gas compressor ¥ and a primary absorber column 8 in contact with the part; the upper part of said separation unit; And a debutanizer column or a column to remove 0 propane in contact with the bottom of the said separator unit. Yio oOo — $ _— 1 4- The catalytic apparatus according to claim 0 (A) also comprising the said primary absorber column Y in connection_ with a gall separating column splitting naphtha column ~~ mentioned. 01-1 The catalytic apparatus according to Claim 0 (1) and also comprising a second column for splitting naphtha gill in connection with said splitting naphtha column Y. -11 1 conversion and fractionation apparatus comprising: a catalytic reactor; a Gall splitting naphtha column ~~ Y in connection with said catalytic reactor; a primary adsorption column in ¥ a posterior connection with said naphtha column; and a receiver in a remote connection with said primary absorber column, and a scavenging column in a remote connection with said receiver. Connection with the overhead of the column ~~ ¥ said main and a shaft for splitting naphtha column Gill; plunge into Y connection with the upper part of the receiver; the splitting naphtha column baill mentioned in M7710 A “connection to upper receiver bottom. -14-1 Switching and fragmentation device according to element of protection (VY) also comprising a compressor in connection ¥ to the upper portion of said upper receiver; a disconnect unit in connection with said compressor; and a Y shaft Primary absorber column sf in connection with the upper part of said separator unit. With said upper receiver bottom and a second catalytic reactor Y in connection with said butane removal column. 11-1 Diverting and doling apparatus of claim (16) also comprising a Y propane removal column in connection with said upper receiver and a second doling in connection with said ¥ propane removing column. 17-1 Diverting and fractionating apparatus As per claim (11); also includes a second splitting naphtha gall column 4 connection with said splitting naphtha column Gil + to provide more separate tall streams. -18 1 catalytic cracker comprising: reactor; a main fractionation column Y in connection with said reactor; and overhead receiver 4 connection with gee ¥ the mentioned main fractionation column; And a column to separate the splitting dill M710 a a a; the naphtha is in contact with the aforementioned upper receptor; a primary (dsl) absorber column 0 8 dimensional connection to said splitting naphtha column; 1 compressor in connection with the upper part of said upper receiver; a unit to separate the liquid part from 1 the compressed gaseous part; and a second compressor In connection with the upper part of said separation unit A to direct additional pressure on the compressed gaseous part, and a column for splitting naphtha column 9 connected to the bottom of said separation unit.