Abstract:
A process is provided that is directed to a steam pyrolysis zone integrated with a solvent deasphalting zone and a hydrotreating zone to permit direct processing of crude oil feedstocks to produce petrochemicals including olefins and aromatics. The integrated solvent deasphalting, hydrotreating and steam pyrolysis process for the direct processing of a crude oil to produce olefinic and aromatic petrochemicals comprises: charging the crude oil to a solvent deasphalting zone with an effective amount of solvent for producing a deasphalted and demetalized oil stream and a bottom asphalt phase; charging the deasphalted and demetalized oil stream and hydrogen to a hydroprocessing zone operating under conditions effective to produce a hydroprocessed effluent reduced having a reduced content of contaminants, an increased paraffinicity, reduced Bureau of Mines Correlation Index, and an increased American Petroleum Institute gravity; thermally cracking the hydroprocessed effluent in the presence of steam to produce a mixed product stream; separating the mixed product stream; purifying hydrogen recovered from the mixed product stream and recycling it to the hydroprocessing zone; recovering olefins and aromatics from the separated mixed product stream; and recovering pyrolysis fuel oil from the separated mixed product stream.

Description:
RELATED APPLICATIONS 
       [0001]    This application This application continuation application of U.S. patent application Ser. No. 13/865,062 filed on Apr. 17, 2013, which 
         [0002]    claims the benefit of priority under 35 USC §119(e) to U.S. Provisional Patent Application No. 61/789,280 filed Mar. 15, 2013, and 
         [0003]    is a Continuation-in-Part under 35 USC §365(c) of PCT Patent Application No. PCT/US13/23334 filed Jan. 27, 2013, which claims the benefit of priority under 35 USC §119(e) to U.S. Provisional Patent Application No. 61/591,780 filed Jan. 27, 2012, all of which are incorporated herein by reference in their entireties. 
     
    
     BACKGROUND OF THE INVENTION 
       [0004]    1. Field of the Invention 
         [0005]    The present invention relates to an integrated solvent deasphalting, hydrotreating and steam pyrolysis process for direct processing of a crude oil to produce petrochemicals such as olefins and aromatics. 
         [0006]    2. Description of Related Art 
         [0007]    The lower olefins (i.e., ethylene, propylene, butylene and butadiene) and aromatics (i.e., benzene, toluene and xylene) are basic intermediates which are widely used in the petrochemical and chemical industries. Thermal cracking, or steam pyrolysis, is a major type of process for forming these materials, typically in the presence of steam, and in the absence of oxygen. Feedstocks for steam pyrolysis can include petroleum gases and distillates such as naphtha, kerosene and gas oil. The availability of these feedstocks is usually limited and requires costly and energy-intensive process steps in a crude oil refinery. 
         [0008]    Studies have been conducted using heavy hydrocarbons as a feedstock for steam pyrolysis reactors. A major drawback in conventional heavy hydrocarbon pyrolysis operations is coke formation. For example, a steam cracking process for heavy liquid hydrocarbons is disclosed in U.S. Pat. No. 4,217,204 in which a mist of molten salt is introduced into a steam cracking reaction zone in an effort to minimize coke formation. In one example using Arabian light crude oil having a Conradson carbon residue of 3.1% by weight, the cracking apparatus was able to continue operating for 624 hours in the presence of molten salt. In a comparative example without the addition of molten salt, the steam cracking reactor became clogged and inoperable after just 5 hours because of the formation of coke in the reactor. 
         [0009]    In addition, the yields and distributions of olefins and aromatics using heavy hydrocarbons as a feedstock for a steam pyrolysis reactor are different than those using light hydrocarbon feedstocks. Heavy hydrocarbons have a higher content of aromatics than light hydrocarbons, as indicated by a higher Bureau of Mines Correlation Index (BMCI). BMCI is a measurement of aromaticity of a feedstock and is calculated as follows: 
         [0000]      BMCI=87552/VAPB+473.5*(sp. gr.)−456.8  (1)
       where:   VAPB=Volume Average Boiling Point in degrees Rankine and   sp. gr.=specific gravity of the feedstock.       
 
         [0013]    As the BMCI decreases, ethylene yields are expected to increase. Therefore, highly paraffinic or low aromatic feeds are usually preferred for steam pyrolysis to obtain higher yields of desired olefins and to avoid higher undesirable products and coke formation in the reactor coil section. 
         [0014]    The absolute coke formation rates in a steam cracker have been reported by Cai et al., “Coke Formation in Steam Crackers for Ethylene Production,”  Chem. Eng . &amp;  Proc ., vol. 41, (2002), 199-214. In general, the absolute coke formation rates are in the ascending order of olefins&gt;aromatics&gt;paraffins, wherein olefins represent heavy olefins 
         [0015]    To be able to respond to the growing demand of these petrochemicals, other type of feeds which can be made available in larger quantities, such as raw crude oil, are attractive to producers. Using crude oil feeds will minimize or eliminate the likelihood of the refinery being a bottleneck in the production of these petrochemicals. 
         [0016]    While the steam pyrolysis process is well developed and suitable for its intended purposes, the choice of feedstocks has been very limited. 
       SUMMARY OF THE INVENTION 
       [0017]    The system and process herein provides a steam pyrolysis zone integrated with a solvent deasphalting zone and a hydrotreating zone to permit direct processing of crude oil feedstocks to produce petrochemicals including olefins and aromatics. 
         [0018]    The integrated solvent deasphalting, hydrotreating and steam pyrolysis process for the direct processing of a crude oil to produce olefinic and aromatic petrochemicals comprises: charging the crude oil to a solvent deasphalting zone with an effective amount of solvent for producing a deasphalted and demetalized oil stream and a bottom asphalt phase; charging the deasphalted and demetalized oil stream and hydrogen to a hydroprocessing zone operating under conditions effective to produce a hydroprocessed effluent having a reduced content of contaminants, an increased paraffinicity, reduced Bureau of Mines Correlation Index, and an increased American Petroleum Institute gravity; thermally cracking the hydroprocessed effluent in the presence of steam to produce a mixed product stream; separating the mixed product stream; purifying hydrogen recovered from the mixed product stream and recycling it to the hydroprocessing zone; recovering olefins and aromatics from the separated mixed product stream; and recovering pyrolysis fuel oil from the separated mixed product stream. 
         [0019]    As used herein, the term “crude oil” is to be understood to include whole crude oil from conventional sources, including crude oil that has undergone some pre-treatment. The term crude oil will also be understood to include that which has been subjected to water-oil separation; and/or gas-oil separation; and/or desalting; and/or stabilization. 
         [0020]    Other aspects, embodiments, and advantages of the process of the present invention are discussed in detail below. Moreover, it is to be understood that both the foregoing information and the following detailed description are merely illustrative examples of various aspects and embodiments, and are intended to provide an overview or framework for understanding the nature and character of the claimed features and embodiments. The accompanying drawings are illustrative and are provided to further the understanding of the various aspects and embodiments of the process of the invention. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0021]    The invention will be described in further detail below and with reference to the attached drawings where: 
           [0022]      FIG. 1  is a process flow diagram of an embodiment of an integrated process described herein; 
           [0023]      FIGS. 2A-2C  are schematic illustrations in perspective, top and side views of a vapor-liquid separation device used in certain embodiments of the integrated process described herein; and 
           [0024]      FIGS. 3A-3C  are schematic illustrations in section, enlarged section and top section views of a vapor-liquid separation device in a flash vessel used in certain embodiments of the integrated process described herein. 
       
    
    
     DETAILED DESCRIPTION OF THE INVENTION 
       [0025]    A flow diagram including an integrated solvent deasphalting, hydrotreating and steam pyrolysis process and system is shown in  FIG. 1 . The system includes a solvent deasphalting zone, a selective hydroprocessing zone, a steam pyrolysis zone and a product separation zone. 
         [0026]    Solvent deasphalting zone includes a primary settler  19 , a secondary settler  22 , a solvent deasphalted/demetalized oil (DA/DMO) separation zone  25 , and a separator zone  27 . Primary settler  19  includes an inlet for receiving a combined stream  18  including a feed stream  1  and a solvent, which can be fresh solvent  16 , recycle solvent  17 , recycle solvent  28 , or a combination of these solvent sources. Primary settler  19  also includes an outlet for discharging a primary DA/DMO phase  20  and several pipe outlets for discharging a primary asphalt phase  21 . Secondary settler  22  includes two tee-type distributors located at both ends for receiving the primary DA/DMO phase  20 , an outlet for discharging a secondary DA/DMO phase  24 , and an outlet for discharging a secondary asphalt phase  23 . DA/DMO separation zone  25  includes an inlet for receiving secondary DA/DMO phase  24 , an outlet for discharging a solvent stream  26  and an outlet for discharging a solvent-free DA/DMO stream  26 , which serves as the feed for the selective hydroprocessing zone. Separator vessel  27  includes an inlet for receiving primary asphalt phase  21 , an outlet for discharging a solvent stream  28 , and an outlet for discharging a bottom asphalt phase  29 , which can be blended with pyrolysis fuel oil  71  from the product separation zone  70 . 
         [0027]    The selective hydroprocessing zone includes a reactor zone  4  includes an inlet for receiving a mixture of the solvent-free DA/DMO stream  26  and hydrogen  2  recycled from the steam pyrolysis product stream, and make-up hydrogen if necessary (not shown). Reactor zone  4  further includes an outlet for discharging a hydroprocessed effluent  5 . 
         [0028]    Reactor effluents  5  from the hydroprocessing reactor(s) are cooled in a heat exchanger (not shown) and sent to a high pressure separator  6 . The separator tops  7  are cleaned in an amine unit  12  and a resulting hydrogen rich gas stream  13  is passed to a recycling compressor  14  to be used as a recycle gas  15  in the hydroprocessing reactor. A bottoms stream  8  from the high pressure separator  6 , which is in a substantially liquid phase, is cooled and introduced to a low pressure cold separator  9  in which it is separated into a gas stream  11  and a liquid stream  10 . Gases from low pressure cold separator include hydrogen, H 2 S, NH 3  and any light hydrocarbons such as C 1 -C 4  hydrocarbons. Typically these gases are sent for further processing such as flare processing or fuel gas processing. According to certain embodiments herein, hydrogen is recovered by combining stream gas stream  11 , which includes hydrogen, H 2 S, NH 3  and any light hydrocarbons such as C 1 -C 4  hydrocarbons, with steam cracker products  44 . Liquid stream  10  serves as the feed to the steam pyrolysis zone  30   
         [0029]    Steam pyrolysis zone  30  generally comprises a convection section  32  and a pyrolysis section  34  that can operate based on steam pyrolysis unit operations known in the art, i.e., charging the thermal cracking feed to the convection section in the presence of steam. In addition, in certain optional embodiments as described herein (as indicated with dashed lines in  FIG. 1 ), a vapor-liquid separation section  36  is included between sections  32  and  34 . Vapor-liquid separation section  36 , through which the heated steam cracking feed from the convection section  32  passes and is fractioned, can be a flash separation device, a separation device based on physical or mechanical separation of vapors and liquids or a combination including at least one of these types of devices. In additional embodiments, a vapor-liquid separation zone  47  is included upstream of sections  32 , either in combination with a vapor-liquid separation zone  36  or in the absence of a vapor-liquid separation zone  36 . Stream  10  is fractioned in separation zone  47 , which can be a flash separation device, a separation device based on physical or mechanical separation of vapors and liquids or a combination including at least one of these types of devices. 
         [0030]    Useful vapor-liquid separation devices are illustrated by, and with reference to  FIGS. 2A-2C and 3A-3C . Similar arrangements of a vapor-liquid separation devices are described in U.S. Patent Publication Number 2011/0247500 which is herein incorporated by reference in its entirety. In this device vapor and liquid flow through in a cyclonic geometry whereby the device operates isothermally and at very low residence time. In general vapor is swirled in a circular pattern to create forces where heavier droplets and liquid are captured and channeled through to a liquid outlet as liquid residue and vapor is channeled through a vapor outlet. In embodiments in which a vapor-liquid separation device  36  is provided, residue  38  is discharged and the vapor is the charge  37  to the pyrolysis section  34 . In embodiments in which a vapor-liquid separation device  47  is provided, residue  49  is discharged and the vapor is the charge  48  to the convection section  32 . The vaporization temperature and fluid velocity are varied to adjust the approximate temperature cutoff point, for instance in certain embodiments compatible with the residue fuel oil blend, e.g., about 540° C. 
         [0031]    Rejected residuals derived from streams  49  and/or  38  have been subjected to the selective hydroprocessing zone and contain a reduced amount of heteroatom compounds including sulfur-containing, nitrogen-containing and metal compounds as compared to the initial feed. This facilitates further processing of these blends, or renders them useful as low sulfur, low nitrogen heavy fuel blends. 
         [0032]    A quenching zone  40  includes an inlet in fluid communication with the outlet of steam pyrolysis zone  30  for receiving mixed product stream  39 , an inlet for admitting a quenching solution  42 , an outlet for discharging the quenched mixed product stream  44  and an outlet for discharging quenching solution  46 . 
         [0033]    In general, an intermediate quenched mixed product stream  44  is converted into intermediate product stream  65  and hydrogen  62 , which is purified in the present process and used as recycle hydrogen stream  2  in the hydroprocessing reaction zone  4 . Intermediate product stream  65  is generally fractioned into end-products and residue in separation zone  70 , which can include one or multiple separation units, for example as is known to one of ordinary skill in the art. For example, suitable apparatus are described in “Ethylene,” Ullmann&#39;s Encyclopedia of Industrial Chemistry, Volume 12, Pages 531-581, in particular  FIG. 24 ,  FIG. 25  and  FIG. 26 , which is incorporated herein by reference. 
         [0034]    In general product separation zone  70  includes an inlet in fluid communication with the product stream  65  and plural product outlets  73 - 78 , including an outlet  78  for discharging methane, an outlet  77  for discharging ethylene, an outlet  76  for discharging propylene, an outlet  75  for discharging butadiene, an outlet  74  for discharging mixed butylenes, and an outlet  73  for discharging pyrolysis gasoline. Additionally an outlet is provided for discharging pyrolysis fuel oil  71 . Optionally, one or both of the bottom asphalt phase  29  from separator vessel  27  and the rejected portion  38  from vapor-liquid separation section  36  are combined with pyrolysis fuel oil  71  and the mixed stream can be withdrawn as a pyrolysis fuel oil blend  72 , e.g., a low sulfur fuel oil blend to be further processed in an off-site refinery. Note that while six product outlets are shown, fewer or more can be provided depending, for instance, on the arrangement of separation units employed and the yield and distribution requirements. 
         [0035]    In an embodiment of a process employing the arrangement shown in  FIG. 1 , a crude oil feedstock  1  is admixed with solvent from one or more sources  16 ,  17  and  28 . The resulting mixture  18  is then transferred to the primary settler  19 . By mixing and settling, two phases are formed in the primary settler  19 : a primary DA/DMO phase  20  and a primary asphalt phase  21 . The temperature of the primary settler  19  is sufficiently low to recover all DA/DMO from the feedstock. For instance, for a system using n-butane a suitable temperature range is about 60° C. to 150° C. and a suitable pressure range is such that it is higher than the vapor pressure of n-butane at the operating temperature e.g. about 15 to 25 bars to maintain the solvent in liquid phase. In a system using n-pentane a suitable temperature range is about 60° C. to about 180° C. and again a suitable pressure range is such that it is higher than the vapor pressure of n-pentane at the operating temperature e.g. about 10 to 25 bars to maintain the solvent in liquid phase. The temperature in the second settler is usually higher than the one in the first settler. 
         [0036]    The primary DA/DMO phase  20  including a majority of solvent and DA/DMO with a minor amount of asphalt is discharged via the outlet located at the top of the primary settler  19  and collector pipes (not shown). The primary asphalt phase  21 , which contains 20-50% by volume of solvent, is discharged via several pipe outlets located at the bottom of the primary settler  19 . 
         [0037]    The primary DA/DMO phase  20  enters into the two tee-type distributors at both ends of the secondary settler  22  which serves as the final stage for the extraction. A secondary asphalt phase  23  containing a small amount of solvent and DA/DMO is discharged from the secondary settler  22  and recycled back to the primary settler  19  to recover DA/DMO. A secondary DA/DMO phase  24  is obtained and passed to the DA/DMO separation zone  25  to obtain a solvent stream  17  and a solvent-free DA/DMO stream  26 . Greater than 90 wt % of the solvent charged to the settlers enters the DA/DMO separation zone  25 , which is dimensioned to permit a rapid and efficient flash separation of solvent from the DA/DMO. The primary asphalt phase  21  is conveyed to the separator vessel  27  for flash separation of a solvent stream  28  and a bottom asphalt phase  29 . Solvent streams  17  and  28  can be used as solvent for the primary settler  19 , therefore minimizing the fresh solvent  16  requirement. 
         [0038]    The solvents used in solvent deasphalting zone include pure liquid hydrocarbons such as propane, butanes and pentanes, as well as their mixtures. The selection of solvents depends on the requirement of DAO, as well as the quality and quantity of the final products. The operating conditions for the solvent deasphalting zone include a temperature at or below critical point of the solvent; a solvent-to-oil ratio in the range of from 2:1 to 50:1 (vol.:vol.); and a pressure in a range effective to maintain the solvent/feed mixture in the settlers is in the liquid state. 
         [0039]    The essentially solvent-free DA/DMO stream  26  is optionally steam stripped (not shown) to remove any remaining solvent, and mixed with an effective amount of hydrogen and  15  (and if necessary a source of make-up hydrogen) to form a combined stream  3 . The admixture  3  is charged to the hydroprocessing reaction zone  4  at a temperature in the range of from 300° C. to 450° C. In certain embodiments, hydroprocessing reaction zone  4  includes one or more unit operations as described in commonly owned United States Patent Publication Number 2011/0083996 and in PCT Patent Application Publication Numbers WO2010/009077, WO2010/009082, WO2010/009089 and WO2009/073436, all of which are incorporated by reference herein in their entireties. For instance, a hydroprocessing zone can include one or more beds containing an effective amount of hydrodemetallization catalyst, and one or more beds containing an effective amount of hydroprocessing catalyst having hydrodearomatization, hydrodenitrogenation, hydrodesulfurization and/or hydrocracking functions. In additional embodiments hydroprocessing reaction zone  4  includes more than two catalyst beds. In further embodiments hydroprocessing reaction zone  4  includes plural reaction vessels each containing one or more catalyst beds, e.g., of different function. 
         [0040]    Hydroprocessing zone  4  operates under parameters effective to hydrodemetallize, hydrodearomatize, hydrodenitrogenate, hydrodesulfurize and/or hydrocrack the crude oil feedstock. In certain embodiments, hydroprocessing is carried out using the following conditions: operating temperature in the range of from 300° C. to 450° C.; operating pressure in the range of from 30 bars to 180 bars; and a liquid hour space velocity in the range of from 0.1 h −1  to 10 h −1 . Notably, using crude oil as a feedstock in the hydroprocessing zone  200  advantages are demonstrated, for instance, as compared to the same hydroprocessing unit operation employed for atmospheric residue. For instance, at a start or run temperature in the range of 370° C. to 375° C. the deactivation rate is around 1° C./month. In contrast, if residue were to be processed, the deactivation rate would be closer to about 3° C./month to 4° C./month. The treatment of atmospheric residue typically employs pressure of around 200 bars whereas the present process in which crude oil is treated can operate at a pressure as low as 100 bars. Additionally to achieve the high level of saturation required for the increase in the hydrogen content of the feed, this process can be operated at a high throughput when compared to atmospheric residue. The LHSV can be as high as 0.5 hr −1  while that for atmospheric residue is typically 0.25 hr −1 . An unexpected finding is that the deactivation rate when processing crude oil is going in the inverse direction from that which is usually observed. Deactivation at low throughput (0.25 hr −1 ) is 4.2° C./month and deactivation at higher throughput (0.5 hr −1 ) is 2.0° C./month. With every feed which is considered in the industry, the opposite is observed. This can be attributed to the washing effect of the catalyst. 
         [0041]    Reactor effluents  5  from the hydroprocessing zone  4  are cooled in an exchanger (not shown) and sent to a high pressure cold or hot separator  6 . Separator tops  7  are cleaned in an amine unit  12  and the resulting hydrogen rich gas stream  13  is passed to a recycling compressor  14  to be used as a recycle gas  15  in the hydroprocessing reaction zone  4 . Separator bottoms  8  from the high pressure separator  6 , which are in a substantially liquid phase, are cooled and then introduced to a low pressure cold separator  9 . Remaining gases, stream  11 , including hydrogen, H 2 S, NH 3  and any light hydrocarbons, which can include C 1 -C 4  hydrocarbons, can be conventionally purged from the low pressure cold separator and sent for further processing, such as flare processing or fuel gas processing. In certain embodiments of the present process, hydrogen is recovered by combining stream  11  (as indicated by dashed lines) with the cracking gas, stream  44 , from the steam cracker products. 
         [0042]    In certain embodiments the bottoms stream  10  is the feed  48  to the steam pyrolysis zone  30 . In further embodiments, bottoms  10  from the low pressure separator  9  are sent to separation zone  47  wherein the discharged vapor portion is the feed  48  to the steam pyrolysis zone  30 . The vapor portion can have, for instance, an initial boiling point corresponding to that of the stream  10  and a final boiling point in the range of about 370° C. to about 600° C. Separation zone  47  can include a suitable vapor-liquid separation unit operation such as a flash vessel, a separation device based on physical or mechanical separation of vapors and liquids or a combination including at least one of these types of devices. Certain embodiments of vapor-liquid separation devices, as stand-alone devices or installed at the inlet of a flash vessel, are described herein with respect to  FIGS. 2A-2C and 3A-3C , respectively. 
         [0043]    The hydroprocessed effluent  10  contains a reduced content of contaminants (i.e., metals, sulfur and nitrogen), an increased paraffinicity, reduced BMCI, and an increased American Petroleum Institute (API) gravity. 
         [0044]    The hydrotreated effluent  10  is passed to the convection section  32  in the presence of an effective amount of steam, e.g., admitted via a steam inlet (not shown). In the convection section  32  the mixture is heated to a predetermined temperature, e.g., using one or more waste heat streams or other suitable heating arrangement. The heated mixture of the pyrolysis feedstream and additional steam is passed to the pyrolysis section  34  to produce a mixed product stream  39 . In certain embodiments the heated mixture of from section  32  is passed through a vapor-liquid separation section  36  in which a portion  38  is rejected as a low sulfur fuel oil component suitable for blending with pyrolysis fuel oil  71 . 
         [0045]    The steam pyrolysis zone  30  operates under parameters effective to crack the hydrotreated effluent  10  or a light portion  48  thereof derived from the optional separation zone  47  into desired products including ethylene, propylene, butadiene, mixed butenes and pyrolysis gasoline. In certain embodiments, steam cracking is carried out using the following conditions: a temperature in the range of from 400° C. to 900° C. in the convection section and in the pyrolysis section; a steam-to-hydrocarbon ratio in the convection section in the range of from 0.3:1 to 2:1 (wt.:wt.); and a residence time in the convection section and in the pyrolysis section in the range of from 0.05 seconds to 2 seconds. 
         [0046]    In certain embodiments, the vapor-liquid separation section  36  includes one or a plurality of vapor liquid separation devices  80  as shown in  FIGS. 2A-2C . The vapor liquid separation device  80  is economical to operate and maintenance free since it does not require power or chemical supplies. In general, device  80  comprises three ports including an inlet port for receiving a vapor-liquid mixture, a vapor outlet port and a liquid outlet port for discharging and the collection of the separated vapor and liquid, respectively. Device  80  operates based on a combination of phenomena including conversion of the linear velocity of the incoming mixture into a rotational velocity by the global flow pre-rotational section, a controlled centrifugal effect to pre-separate the vapor from liquid (residue), and a cyclonic effect to promote separation of vapor from the liquid (residue). To attain these effects, device  80  includes a pre-rotational section  88 , a controlled cyclonic vertical section  90  and a liquid collector/settling section  92 . 
         [0047]    As shown in  FIG. 2B , the pre-rotational section  88  includes a controlled pre-rotational element between cross-section (S 1 ) and cross-section (S 2 ), and a connection element to the controlled cyclonic vertical section  90  and located between cross-section (S 2 ) and cross-section (S 3 ). The vapor liquid mixture coming from inlet  82  having a diameter (D 1 ) enters the apparatus tangentially at the cross-section (S 1 ). The area of the entry section (S 1 ) for the incoming flow is at least 10% of the area of the inlet  82  according to the following equation: 
         [0000]    
       
         
           
             
               
                 
                   
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                         ( 
                         
                           [ 
                           
                             D 
                              
                             
                                 
                             
                              
                             1 
                           
                           ) 
                         
                         ] 
                       
                       2 
                     
                   
                   4 
                 
               
               
                 
                   ( 
                   2 
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         [0048]    The pre-rotational element  88  defines a curvilinear flow path, and is characterized by constant, decreasing or increasing cross-section from the inlet cross-section S 1  to the outlet cross-section S 2 . The ratio between outlet cross-section from controlled pre-rotational element (S 2 ) and the inlet cross-section (S 1 ) is in certain embodiments in the range of 0.7≦S 2 /S 1 ≦1.4. 
         [0049]    The rotational velocity of the mixture is dependent on the radius of curvature (R 1 ) of the center-line of the pre-rotational element  38  where the center-line is defined as a curvilinear line joining all the center points of successive cross-sectional surfaces of the pre-rotational element  88 . In certain embodiments the radius of curvature (R 1 ) is in the range of 2≦R 1 /D 1 ≦6 with opening angle in the range of 150°≦αR 1 ≦250°. 
         [0050]    The cross-sectional shape at the inlet section S 1 , although depicted as generally square, can be a rectangle, a rounded rectangle, a circle, an oval, or other rectilinear, curvilinear or a combination of the aforementioned shapes. In certain embodiments, the shape of the cross-section along the curvilinear path of the pre-rotational element  38  through which the fluid passes progressively changes, for instance, from a generally square shape to a rectangular shape. The progressively changing cross-section of element  88  into a rectangular shape advantageously maximizes the opening area, thus allowing the gas to separate from the liquid mixture at an early stage and to attain a uniform velocity profile and minimize shear stresses in the fluid flow. 
         [0051]    The fluid flow from the controlled pre-rotational element  88  from cross-section (S 2 ) passes section (S 3 ) through the connection element to the controlled cyclonic vertical section  90 . The connection element includes an opening region that is open and connected to, or integral with, an inlet in the controlled cyclonic vertical section  90 . The fluid flow enters the controlled cyclonic vertical section  90  at a high rotational velocity to generate the cyclonic effect. The ratio between connection element outlet cross-section (S 3 ) and inlet cross-section (S 2 ) in certain embodiments is in the range of 2≦S 3 /S 1 ≦5. 
         [0052]    The mixture at a high rotational velocity enters the cyclonic vertical section  90 . Kinetic energy is decreased and the vapor separates from the liquid under the cyclonic effect. Cyclones form in the upper level  90   a  and the lower level  90   b  of the cyclonic vertical section  90 . In the upper level  90   a , the mixture is characterized by a high concentration of vapor, while in the lower level  90   b  the mixture is characterized by a high concentration of liquid. 
         [0053]    In certain embodiments, the internal diameter D 2  of the cyclonic vertical section  90  is within the range of 2≦D 2 /D 1 ≦5 and can be constant along its height, the length (LU) of the upper portion  90   a  is in the range of 1.2≦LU/D 2 ≦3, and the length (LL) of the lower portion  90   b  is in the range of 2≦LL/D 2 ≦5. 
         [0054]    The end of the cyclonic vertical section  90  proximate vapor outlet  84  is connected to a partially open release riser and connected to the pyrolysis section of the steam pyrolysis unit. The diameter (DV) of the partially open release is in certain embodiments in the range of 0.05≦DV/D 2 ≦0.4. 
         [0055]    Accordingly, in certain embodiments, and depending on the properties of the incoming mixture, a large volume fraction of the vapor therein exits device  80  from the outlet  84  through the partially open release pipe with a diameter DV. The liquid phase (e.g., residue) with a low or non-existent vapor concentration exits through a bottom portion of the cyclonic vertical section  80  having a cross-sectional area S 4 , and is collected in the liquid collector and settling pipe  42 . 
         [0056]    The connection area between the cyclonic vertical section  90  and the liquid collector and settling pipe  92  has an angle in certain embodiments of 90°. In certain embodiments the internal diameter of the liquid collector and settling pipe  92  is in the range of 2≦D 3 /D 1 ≦4 and is constant across the pipe length, and the length (LH) of the liquid collector and settling pipe  92  is in the range of 1.2≦LH/D 3 ≦5. The liquid with low vapor volume fraction is removed from the apparatus through pipe  86  having a diameter of DL, which in certain embodiments is in the range of 0.05≦DL/D 3 ≦0.4 and located at the bottom or proximate the bottom of the settling pipe. 
         [0057]    In certain embodiments, a vapor-liquid separation device is provided similar in operation and structure to device  80  without the liquid collector and settling pipe return portion. For instance, a vapor-liquid separation device  180  is used as inlet portion of a flash vessel  179 , as shown in  FIGS. 3A-3C . In these embodiments the bottom of the vessel  179  serves as a collection and settling zone for the recovered liquid portion from device  180 . 
         [0058]    In general a vapor phase is discharged through the top  194  of the flash vessel  179  and the liquid phase is recovered from the bottom  196  of the flash vessel  179 . The vapor-liquid separation device  180  is economical to operate and maintenance free since it does not require power or chemical supplies. Device  180  comprises three ports including an inlet port  182  for receiving a vapor-liquid mixture, a vapor outlet port  184  for discharging separated vapor and a liquid outlet port  186  for discharging separated liquid. Device  180  operates based on a combination of phenomena including conversion of the linear velocity of the incoming mixture into a rotational velocity by the global flow pre-rotational section, a controlled centrifugal effect to pre-separate the vapor from liquid, and a cyclonic effect to promote separation of vapor from the liquid. To attain these effects, device  180  includes a pre-rotational section  188  and a controlled cyclonic vertical section  190  having an upper portion  190   a  and a lower portion  190   b . The vapor portion having low liquid volume fraction is discharged through the vapor outlet port  184  having a diameter (DV). Upper portion  190   a  which is partially or totally open and has an internal diameter (DII) in certain embodiments in the range of 0.5&lt;DV/DII&lt;1.3. The liquid portion with low vapor volume fraction is discharged from liquid port  186  having an internal diameter (DL) in certain embodiments in the range of 0.1&lt;DL/DII&lt;1.1. The liquid portion is collected and discharged from the bottom of flash vessel  179 . 
         [0059]    In order to enhance and to control phase separation, heating steam can be used in the vapor-liquid separation device  80  or  180 , particularly when used as a standalone apparatus or is integrated within the inlet of a flash vessel. 
         [0060]    While the various members are described separately and with separate portions, it will be understood by one of ordinary skill in the art that apparatus  80  or apparatus  180  can be formed as a monolithic structure, e.g., it can be cast or molded, or it can be assembled from separate parts, e.g., by welding or otherwise attaching separate components together which may or may not correspond precisely to the members and portions described herein. 
         [0061]    It will be appreciated that although various dimensions are set forth as diameters, these values can also be equivalent effective diameters in embodiments in which the components parts are not cylindrical. 
         [0062]    Mixed product stream  39  is passed to the inlet of quenching zone  40  with a quenching solution  42  (e.g., water and/or pyrolysis fuel oil) introduced via a separate inlet to produce a quenched mixed product stream  44  having a reduced temperature, e.g., of about 300° C., and spent quenching solution  46  is discharged. 
         [0063]    The gas mixture effluent  39  from the cracker is typically a mixture of hydrogen, methane, hydrocarbons, carbon dioxide and hydrogen sulfide. After cooling with water or oil quench, mixture  44  is compressed in a multi-stage compressor zone  51 , typically in 4-6 stages to produce a compressed gas mixture  52 . The compressed gas mixture  52  is treated in a caustic treatment unit  53  to produce a gas mixture  54  depleted of hydrogen sulfide and carbon dioxide. The gas mixture  54  is further compressed in a compressor zone  55 , and the resulting cracked gas  56  typically undergoes a cryogenic treatment in unit  57  to be dehydrated, and is further dried by use of molecular sieves. 
         [0064]    The cold cracked gas stream  58  from unit  57  is passed to a de-methanizer tower  59 , from which an overhead stream  60  is produced containing hydrogen and methane from the cracked gas stream. The bottoms stream  65  from de-methanizer tower  59  is then sent for further processing in product separation zone  70 , comprising fractionation towers including de-ethanizer, de-propanizer and de-butanizer towers. Process configurations with a different sequence of de-methanizer, de-ethanizer, de-propanizer and de-butanizer can also be employed. 
         [0065]    According to the processes herein, after separation from methane at the de-methanizer tower  59  and hydrogen recovery in unit  61 , hydrogen  62  having a purity of typically 80-95 vol % is obtained. Recovery methods in unit  61  include cryogenic recovery (e.g., at a temperature of about −157° C.). Hydrogen stream  62  is then passed to a hydrogen purification unit  64 , such as a pressure swing adsorption (PSA) unit to obtain a hydrogen stream  2  having a purity of 99.9%+, or a membrane separation units to obtain a hydrogen stream  2  with a purity of about 95%. The purified hydrogen stream  2  is then recycled back to serve as a major portion of the requisite hydrogen for the hydroprocessing zone. In addition, a minor proportion can be utilized for the hydrogenation reactions of acetylene, methylacetylene and propadienes (not shown). In addition, according to the processes herein, methane stream  63  can optionally be recycled to the steam cracker to be used as fuel for burners and/or heaters. 
         [0066]    The bottoms stream  65  from de-methanizer tower  59  is conveyed to the inlet of product separation zone  70  to be separated into methane, ethylene, propylene, butadiene, mixed butylenes and pyrolysis gasoline via outlets  78 ,  77 ,  76 ,  75 ,  74  and  73 , respectively. Pyrolysis gasoline generally includes C5-C9 hydrocarbons, and benzene, toluene and xylenes can be extracted from this cut. Optionally one or both of the bottom asphalt phase  29  and the unvaporized heavy liquid fraction  38  from the vapor-liquid separation section  36  are combined with pyrolysis fuel oil  71  (e.g., materials boiling at a temperature higher than the boiling point of the lowest boiling C10 compound, known as a “C10+” stream) from separation zone  70 , and the mixed stream is withdrawn as a pyrolysis fuel oil blend  72 , e.g., to be further processed in an off-site refinery (not shown). In certain embodiments, the bottom asphalt phase  29  can be sent to an asphalt stripper (not shown) where any remaining solvent is stripped-off, e.g., by steam. 
         [0067]    Solvent deasphalting is a unique separation process in which residue is separated by molecular weight (density), instead of by boiling point, as in the vacuum distillation process. The solvent deasphalting process thus produces a low-contaminant deasphalted oil (DAO) rich in paraffinic type molecules, consequently decreases the BMCI as compared to the initial feedstock or the hydroprocessed feedstock. 
         [0068]    Solvent deasphalting is usually carried out with paraffin streams having carbon number ranging from 3-7, in certain embodiments ranging from 4-5, and below the critical conditions of the solvent. Table 1 lists the properties of commonly used solvents in solvent deasphalting. 
         [0000]    
       
         
               
             
               
               
               
               
               
               
               
             
               
               
               
               
               
               
               
             
           
               
                 TABLE 1 
               
             
             
               
                   
               
               
                 Properties Of Commonly Used Solvents In Solvent Deasphalting 
               
             
          
           
               
                   
                   
                   
                 Boiling 
                   
                 Critical 
                 Critical 
               
               
                   
                   
                 MW 
                 Point 
                 Specific 
                 Temperature 
                 Pressure 
               
               
                 Name 
                 Formula 
                 g/g-mol 
                 ° C. 
                 Gravity 
                 ° C. 
                 bar 
               
               
                   
               
             
          
           
               
                 propane 
                 C3 H8 
                 44.1 
                 −42.1 
                 0.508 
                 96.8 
                 42.5 
               
               
                 n-butane 
                 C4 H10 
                 58.1 
                 −0.5 
                 0.585 
                 152.1 
                 37.9 
               
               
                 i--butane 
                 C4 H10 
                 58.1 
                 −11.7 
                 0.563 
                 135.0 
                 36.5 
               
               
                 n-pentane 
                 C5 H12 
                 72.2 
                 36.1 
                 0.631 
                 196.7 
                 33.8 
               
               
                 i--pentane 
                 C5 H12 
                 72.2 
                 27.9 
                 0.625 
                 187.3 
                 33.8 
               
               
                   
               
             
          
         
       
     
         [0069]    The feed is mixed with a light paraffinic solvent with carbon numbers ranging 3-7, where the deasphalted oil is solubilized in the solvent. The insoluble pitch will precipitate out of the mixed solution and is separated from the DAO phase (solvent-DAO mixture) in the extractor. 
         [0070]    Solvent deasphalting is carried-out in liquid phase and therefore the temperature and pressure are set accordingly. There are two stages for phase separation in solvent deasphalting. In the first separation stage, the temperature is maintained lower than that of the second stage to separate the bulk of the asphaltenes. The second stage temperature is maintained to control the deasphalted/demetalized oil (DA/DMO) quality and quantity. The temperature has big impact on the quality and quantity of DA/DMO. An extraction temperature increase will result in a decrease in deasphalted/demetalized oil yield, which means that the DA/DMO will be lighter, less viscous, and contain less metals, asphaltenes, sulfur, and nitrogen. A temperature decrease will have the opposite effects. In general, the DA/DMO yield decreases having higher quality by raising extraction system temperature and increases having lower quality by lowering extraction system temperature. 
         [0071]    The composition of the solvent is an important process variable. The solubility of the solvent increases with increasing critical temperature, generally according to C3&lt;iC4&lt;nC4&lt;iC5. An increase in critical temperature of the solvent increases the DA/DMO yield. However, it should be noted that the solvent having the lower critical temperature has less selectivity resulting in lower DA/DMO quality. 
         [0072]    The volumetric ratio of the solvent to the solvent deasphalting unit charge impacts selectivity and to a lesser degree on the DA/DMO yield. Higher solvent-to-oil ratios result in a higher quality of the DA/DMO for a fixed DA/DMO yield. Higher solvent-to-oil ratio is desirable due to better selectivity, but can result in increased operating costs thereby the solvent-to-oil ratio is often limited to a narrow range. The composition of the solvent will also help to establish the required solvent to oil ratios. The required solvent to oil ratio decreases as the critical solvent temperature increases. The solvent to oil ratio is, therefore, a function of desired selectivity, operation costs and solvent composition. 
         [0073]    In certain embodiments, selective hydroprocessing or hydrotreating processes can increase the paraffin content (or decrease the BMCI) of a feedstock by saturation followed by mild hydrocracking of aromatics, especially polyaromatics. When hydrotreating a crude oil, contaminants such as metals, sulfur and nitrogen can be removed by passing the feedstock through a series of layered catalysts that perform the catalytic functions of demetallization, desulfurization and/or denitrogenation. 
         [0074]    In one embodiment, the sequence of catalysts to perform hydrodemetallization (HDM) and hydrodesulfurization (HDS) is as follows: 
         [0075]    A hydrodemetallization catalyst. The catalyst in the HDM section are generally based on a gamma alumina support, with a surface area of about 140-240 m 2 /g. This catalyst is best described as having a very high pore volume, e.g., in excess of 1 cm 3 /g. The pore size itself is typically predominantly macroporous. This is required to provide a large capacity for the uptake of metals on the catalysts surface and optionally dopants. Typically the active metals on the catalyst surface are sulfides of Nickel and Molybdenum in the ratio Ni/Ni+Mo&lt;0.15. The concentration of Nickel is lower on the HDM catalyst than other catalysts as some Nickel and Vanadium is anticipated to be deposited from the feedstock itself during the removal, acting as catalyst. The dopant used can be one or more of phosphorus (see, e.g., United States Patent Publication Number US 2005/0211603 which is incorporated by reference herein), boron, silicon and halogens. The catalyst can be in the form of alumina extrudates or alumina beads. In certain embodiments alumina beads are used to facilitate un-loading of the catalyst HDM beds in the reactor as the metals uptake will range between from 30 to 100% at the top of the bed. 
         [0076]    An intermediate catalyst can also be used to perform a transition between the HDM and HDS function. It has intermediate metals loadings and pore size distribution. The catalyst in the HDM/HDS reactor is essentially alumina based support in the form of extrudates, optionally at least one catalytic metal from group VI (e.g., molybdenum and/or tungsten), and/or at least one catalytic metals from group VIII (e.g., nickel and/or cobalt). The catalyst also contains optionally at least one dopant selected from boron, phosphorous, halogens and silicon. Physical properties include a surface area of about 140-200 m 2 /g, a pore volume of at least 0.6 cm 3 /g and pores which are mesoporous and in the range of 12 to 50 nm. 
         [0077]    The catalyst in the HDS section can include those having gamma alumina based support materials, with typical surface area towards the higher end of the HDM range, e.g. about ranging from 180-240 m 2 /g. This required higher surface for HDS results in relatively smaller pore volume, e.g., lower than 1 cm 3 /g. The catalyst contains at least one element from group VI, such as molybdenum and at least one element from group VIII, such as nickel. The catalyst also comprises at least one dopant selected from boron, phosphorous, silicon and halogens. In certain embodiments cobalt is used to provide relatively higher levels of desulfurization. The metals loading for the active phase is higher as the required activity is higher, such that the molar ratio of Ni/Ni+Mo is in the range of from 0.1 to 0.3 and the (Co+Ni)/Mo molar ratio is in the range of from 0.25 to 0.85. 
         [0078]    A final catalyst (which could optionally replace the second and third catalyst) is designed to perform hydrogenation of the feedstock (rather than a primary function of hydrodesulfurization), for instance as described in Appl. Catal. A General, 204 (2000) 251. The catalyst will be also promoted by Ni and the support will be wide pore gamma alumina. Physical properties include a surface area towards the higher end of the HDM range, e.g., 180-240 m 2 /g. This required higher surface for HDS results in relatively smaller pore volume, e.g., lower than 1 cm 3 /g. 
         [0079]    The method and system herein provides improvements over known steam pyrolysis cracking processes: 
         [0000]    use of crude oil as a feedstock to produce petrochemicals such as olefins and aromatics; 
         [0080]    the hydrogen content of the feed to the steam pyrolysis zone is enriched for high yield of olefins; 
         [0081]    coke precursors are significantly removed from the initial whole crude oil which allows a decreased coke formation in the radiant coil; 
         [0082]    additional impurities such as metals, sulfur and nitrogen compounds are also significantly removed from the starting feed which avoids post treatments of the final products. 
         [0083]    In addition, hydrogen produced from the steam cracking zone is recycled to the hydroprocessing zone to minimize the demand for fresh hydrogen. In certain embodiments the integrated systems described herein only require fresh hydrogen to initiate the operation. Once the reaction reaches the equilibrium, the hydrogen purification system can provide enough high purity hydrogen to maintain the operation of the entire system. 
         [0084]    The method and system of the present invention have been described above and in the attached drawings; however, modifications will be apparent to those of ordinary skill in the art and the scope of protection for the invention is to be defined by the claims that follow.