JP6378094B2 - High yield conversion of heavy hydrocarbons with low complexity - Google Patents

Description

  The present invention improves heavy hydrocarbons such as bitumen, lighter and more fluid products, and more particularly refinery-ready and without the addition of diluent It relates to an optimized method for obtaining a final hydrocarbon product that meets transportation standards. Solid asphaltene by-products are produced that can be easily handled and processed further. The present invention aims to improve Canadian bitumen, and the present invention has general application in the improvement of all heavy hydrocarbons.

In order to improve the feasibility of converting heavy, viscous hydrocarbons to the desired refinery feedstock and its economics, a low complexity, high yield integrated process has been developed, Has been tested and improved. This integrated method concept was previously described in U.S. Patent Application Nos. 13/037185 and 13/250935, and through pilot plant (5 BPD) and demo scale (1500 BPD) equipment. It has been verified. Improvements to the integrated method by shear mixing are described in US patent application Ser. No. 61/548915.
The present invention describes optimal operating conditions to achieve the lowest complexity and highest yield for the described integrated method. The integrated method operates at temperatures, pressures, heat fluxes, residence times, sweep gas ratios and solvent to oil ratios outside any open art method in the art. The reduced capital and operating costs associated with this new integrated method, derived from all these new combinations of conditions and solvent choices, along with its high liquid product yields, are for any heavy oil manufacturer. Give you the opportunity to earn high profits.

(Description of prior art)
Various methods have been disclosed for adding and / or conditioning oil sand bitumen to crude oil that is transportable by pipeline and acceptable to refineries. Of note, pyrolysis, catalytic cracking, solvent history, and combinations of these three methods (e.g., a combination of visbreaking and solvent descaling) convert bitumen as feedstock for refineries. It has been proposed to improve its characteristics for transport and use.

Is a form of pyrolysis pyrolysis, visbreaking, i.e. visco City braking is a well-known petroleum refining process, in the method, heavy and / or reduced crude, relatively mild conditions Pyrolyzed, or decomposed to yield a product with a lower viscosity and pour point. The result is a blend of hydrocarbons known as diluents to reduce a certain amount of low viscosity and gradually increasing cost to improve the fluidity of the crude oil, and the crude oil In addition, the minimum standard value for transport pipeline (19 minimum API specific gravity) is satisfied.

There are two basic visbreaking configurations: a coil-only bisbreaker and a coil-and-soak bisbreaker. Both of them require a heater for heating the crude oil, and the coil-only type uses decomposition only in the heater tube. The coil-only screw breaker operates at about 482 ° C. (about 900 ° F.) at the heater outlet with a residence time of about 1 minute. Gas oil is recirculated to stop the reaction. In the coil and soak screw breaker, a vessel is used at the furnace outlet to provide additional residence time for the cracking of the crude oil. The crude oil is left to stand and continues to decompose / react as its temperature gradually decreases. The coil and soak screw breaker is operated at a heater outlet temperature of about 427 ° C. (800 ° F.). The soap ram temperature drops to about 371 ° C. (700 ° F.) at the outlet, where the total residence time exceeds 1 hour.
Examples of such visbreaking methods are Beuther et al., “Thermal Visbreaking of Heavy Residues”, The Oil and Gas Journal, 57:46, Nov 9, 1959, pp. 151-157; Rhoe et al., “Visbreaking: A Flexible Process”, Hydrocarbon Processing, Jan., 1979, pp. 131-136; And in U.S. Pat. No. 4,233,138. The yield structure is almost the same for all configurations: 1-3% light end; 5% (wt) naphtha and 15% (vt) gas oil. The balance remains heavy oil or bitumen. These products are separated in a distillation column for further processing or blending purposes.

One problem with standard visbreaking schemes is that, in connection with Canadian bitumen, the operating temperature exceeds its limit (ranging from about 371 ° C to about 382 ° C (700 ° F-720 ° F)). In particular, significant coking here has affected feasibility (Golden & Bartletta, Designing Vacuum Units (for Canadian heavy crudes)), Petro (Petroleum Technology Quarterly), Q2, 2006, pp. 105). Furthermore, heat is applied in the heater for a short period of time, so that the local heat flux is not irregular and can peak at a position well above the coking start limit. In addition, the heat is not constantly maintained, allowing the condensation reaction to occur. Attempts to apply traditional visbreaking methods to Canadian bitumen are limited due to the coking tendency and the inability of these systems to address this issue.
In the main part of US Pat. No. 6,972,085 and US Pat. No. 7,976,695, attempts have been made to address the demands of applying constant and persistent heat to crude oil over a long period of time. In essence, the heater and holding vessel are merged into a single vessel to produce a continuous heating bath for the crude oil. At various times, multiple levels of heating are applied to the crude oil. This is one improvement over standard visbreaking methods, but does not preclude the formation of hot spots in the treated crude oil, and because of temperature peaks above the optimum level for cracking, Caulking will occur.

US Pat.No. 4,454,023 discloses a method for treating heavy and viscous hydrocarbon oils, which is a combination of pyrolysis / catalytic cracking and solvent descaling. A step of fractionating the visbroken oil; a two-stage dehistory treatment, wherein a non-distilled portion of the visbreaked oil is subjected to a solvent degrease treatment; Regenerating the asphaltene, resin, and a history of oil history; mixing the history oil (DAO) with the visbreaked fraction; Circulating and combining it with the feedstock initially fed to the bisbreaker. This U.S. Patent No. '023 provides a means to upgrade lighter hydrocarbons (API degree (specific gravity)> 15) than Canadian bitumen, but will overdecompose and coking the hydrocarbon stream. Burdened by the complexity and cost of a two-stage solvent devolatilization system, due to incorrect application of the above-mentioned pyrolysis technique and to separate the resin fraction from the devolatilized oil Yes. Furthermore, the need to recycle a portion of the resin stream increases operating costs and operational complexity.
In U.S. Pat. No. 4,191,636, heavy oil is free of asphaltenes and metals continuously by hydrotreating the heavy oil to selectively decompose asphaltenes and remove heavy metals such as nickel and vanadium at the same time. Converted to oil. The liquid product is separated into a light fraction of asphaltene-free and metal-free oil and a heavy fraction of asphaltene-containing and heavy metal-containing oil. The light fraction is recovered as a product and the heavy fraction is recycled to the hydroprocessing step. Catalytic conversion of Canadian heavy bitumen (API specific gravity <10) using the method described in this patent '636 affects reliability and rapid catalyst deactivation, affecting selectivity and yield. It is a powerful method that tends to have problems.

In U.S. Pat. No. 4,428,824, a solvent escape unit is installed upstream of the visbreaking unit to remove asphaltenes resulting from the visbreaking operation. In this configuration, the visbreaking unit can now operate at higher temperatures to convert heavier molecules to lighter hydrocarbon molecules without any interruption. This is because the asphaltenes have been completely removed from the product stream. However, the yield of the bitumen is greatly reduced (only 10-15%). This is because the initial removal of the asphaltenes in this process hinders the thermal conversion of that portion of the crude oil to a refinable product.
As in U.S. Pat.No. 4,428,824, U.S. Pat.No. 6,274,032 discloses a method for treating a hydrocarbon feedstock, which includes a rectifying column for separating main crude components, It then includes a solvent desaturation (SAD) unit that operates on heavier crude asphaltenic components and a mild pyrolysis apparatus for non-asphaltenic streams. The asphaltene rich stream is processed in a gasification unit to generate synthesis gas (syngas) for hydrogen demand. By placing the SDA unit upstream of the pyrolysis unit, the overall yield of the bitumen as refinery feedstock is reduced. This is because the asphaltene portion of the crude, which comprises up to 15% of Canadian bitumen, is excluded from consideration for inclusions in certain forms as crude. This loss in product yield is not compensated by the high degradability in the bisbreaker.

U.S. Pat.No. 4,686,028 discloses a process for treating whole crude oil, which involves hydrocarbons in the high boiling range in a two-stage deregulation process to separate separate asphaltenes, resins. And generating a history oil fraction, and then upgrading by only hydrogenating or visbreaking the resin fraction. The invention of U.S. Pat. No. 4,686,028 minimizes coke generation by subjecting a convenient portion of the total crude oil stream to visbreaking. However, this patent '028 is limited by losing the bulk of the crude that can benefit from optimal conversion, so the bulk of the crude is a need for a shipping diluent. None of them will eventually become a pipeline product.
U.S. Pat.No. 5,601,697 discloses a method for treating truncated crude oil, the method comprising vacuum-distilling the truncated crude oil, degassing the residual product resulting from the distillation, and Catalytically cracked and mixed with a distillable catalytic cracking fraction (atmospheric equivalent boiling point of about 593 ° C (about 1100 ° F)) to produce a product containing transportation fuel, light gas, and slurry oil. The manufacturing process is included. U.S. Pat. No. '697 is complex, cost-effective, and vacuum-distilled heavy crude oil extracted to about 454 ° C. (about 850 ° F.) and catalytically cracked the deregulated oil to produce transportation fuel Will be burdened by the technical feasibility of this.

In US Pat. No. 6,533,925, solvent deregulation is integrated with a gasification process and an improved method for separating the resin phase from a solvent solution containing solvent, de-histored oil (DAO) and resin. Is disclosed. A resin extractor using a solvent having a temperature higher than that of the first asphaltene extractor is included in the invention of the present patent '925. The asphaltene stream is processed but removed prior to any thermal conversion process, eliminating the possibility of adding value to a usable refinery feedstock. The effect is a reduction in the possible overall yield of the crude oil stream.
In U.S. Patent Application No. 2007/0125686, a method is disclosed, in which a heavy hydrocarbon stream is first separated into various fractions by distillation, the heavy components of which are heated with mild heat. It is sent to the disassembly device (screw breaker). The remaining heavy liquid from the mild pyrolyzer is solvent escaped in the SDA unit of the published technology. The asphaltenes separated from the SDA are used as a feedstock for the gasifier. The history oil is blended with condensed mild pyrolyzer vapor to produce a blended product. As described in the above patent '023, visbreaking faces the challenge of early coke generation. Specifically, the patent application '686 explains that the intention to use this mild pyrolysis apparatus is to decompose only non-asphaltenic materials, It is not practical for bitumen produced in Japan. In this patent application, the mild pyrolysis apparatus is operated under high pressure conditions, which unnecessarily increases the production of coke and consequently its yield. In addition, additional energy is required in the distillation and extraction process, and most of the separated and multi-component will be recombined for pipeline transportation.

  In U.S. Pat.No. 8,048,291, a method is disclosed in which residual liquid from atmospheric and / or vacuum columns is treated in a solvent devolatilization unit and then in some embodiments pyrolysis or Processed by catalytic cracking. The purpose of this patent is to reduce the cost of decomposing the DAO stream by placing SDA upstream of the decomposing unit. Multiple extraction steps and the operating conditions of the SDA increase the overall cost of the method, offsetting some of the savings from smaller decomposition units, and the integrated method increases yield Thus, if the cost of adding hydrogen is not incurred, a lower overall yield will be incurred. The SDA unit removes the heavy asphaltenes that make up more than 15% of the heavy bitumen stream and consequently limits the overall yield to less than 85% when the expensive contact method is not used Resulting in. The overall result of this method is uneconomical and the limits of the feedstock processed are above 5 API by the SDA.

Treatment of asphaltene-rich streams generated by SDA In U.S. Pat.No. 4,421,639, the solvent desaturation method uses a second asphalt extractor to concentrate asphaltene material (and recover more desaturated oil). ing. The concentrated asphalt stream is sent to a heater to about 218 ° C. (425 ° F.) at about 0.124 MPa absolute pressure (18 psia), and from the asphalt stream using a flash drum and a flow stripper. (In this case propane) is separated. Asphalt products in a liquid neck are pumped for storage. This arrangement only works when the asphalt-rich stream is liquid at these conditions. If any significant amount of solid asphaltenes is present, such as in bitumen-rich streams, it is subject to clogging loads.

In U.S. Pat. No. 3,847,751, the rich asphaltene product from the SDA unit is mixed with a solvent and conveyed as a liquid solution to a spray dryer. The spray nozzle design and pressure drop determine the size of the liquid droplets that are formed. The smaller the light hydrocarbon (solvent) droplets, the faster and completely evaporates. The smaller the heavy hydrocarbon (asphalten) particles, the greater the surface area available for heat transfer to cool the heavy droplets for the purpose of producing dry non-sticky solid particles. Additional cooling gas is added to the bottom of the spray dryer, resulting in enhanced cooling by concomitant convective heat transfer and by reducing the drop rate of the droplets (due to the upward cooling gas flow). Increase the residence time to reduce the size of the container (which tends to be very large). This arrangement is not required when the asphaltene particles precipitated in the extractor are in solid form in the solvent at the operating temperature of the process.
U.S. Pat. No. 4,278,529 exemplifies a method for separating a solvent from a bituminous material by a pressure drop without introducing a bitumen-based material. The pressure of the fluid phase containing bitumenous material and solvent is reduced by passing a pressure reducing valve, and the phase is introduced into a steam stripper. The decrease in pressure vaporizes a part of the solvent and disperses a mist of fine bitumen-based particles in the solvent. The problem with this method is that the residual asphaltenes remain in a wet and sticky state and leave enough solvent to keep the heavy bituminous phase (including many solids) in a fluid state. Not.

In U.S. Pat.No. 4,572,781, a centrifugal decanter is used to separate substantially dry asphaltenes with high softening points from heavy hydrocarbon materials and separate the liquid phase from a highly concentrated slurry of solid asphaltenes. A solvent escape history method is described. This method is intended for the treatment of a concentrated asphaltene stream with solid particles, but the solid separation involves the addition of additional solvent due to the need to flow the material to the decanter. / Because it is performed by liquid separation, it is a very expensive method. At all times, the separated solid material still contains relatively high moisture and requires a separate drying step to recover the solvent as a vapor. The solvent vapor needs to be condensed for reuse, which requires a separate high energy process.
In U.S. Pat.No. 5,009,772, a process related to a continuous, relatively low temperature history process is shown in which a heavy hydrocarbon feedstock material and an extraction solvent are combined with a highly subcritical process. Contacting within the extraction zone at temperature and superatmospheric pressure produces a light extraction phase and a heavy phase rich in higher molecular weight hydrocarbon components, Conradson carbon precursors and heavy metals. This U.S. Pat.No. 5,009,772 involves continuously reducing the pressure on the first light extraction phase produced in the extraction zone, which is less than supercritical conditions in the SDA unit. This suggests that there are several benefits to the operation. However, further improvements in the overall process may be utilized to allow heavier crude oil to be processed in a simpler, less expensive manner.

  In US Pat. No. 7,597,794, after separation by solvent extraction, a dispersed solvent is introduced into the asphalt phase, and the asphalt phase undergoes a rapid phase change in the gas-solid separator and is dispersed within the solid particles. While the solvent evaporates, resulting in a low temperature separation of the asphalt from the solvent containing the asphalt particles of adjustable size. The challenge with flash / spray dryers that use liquid solvents as the transport medium is the tendency of the asphaltenes produced in this process to remain wet before, during and after the flash drying stage. Furthermore, according to this method, the asphaltenes continue to liquefy at high temperatures. Asphaltene in the wet state will adhere to any surface and will easily contaminate and clog the equipment. The reduced reliability resulting from the use of this method makes this operation costly for heavy crudes with high asphaltene content. Example 6 of this patent uses heavy crude oil with an API of 2, in which the overall DAO yield achieved is 83.5% and the solvent recovery is over 80%. . Both of these values indicate that this is an uneconomical process and can be significantly improved.

  U.S. Pat.No. 7,749,378 illustrates a method for transporting and upgrading heavy oil or bitumen, which method comprises 3-8 carbon atoms at the site of manufacture thereof. Diluting with a hydrocarbon-containing diluent having a concentration of; carrying the mixture from the manufacturing site to a solvent devolatilization unit; degassing the mixture within the solvent eviction unit; Recovering an asphaltene fraction, an essentially asphaltene-free historical oil fraction and a solvent fraction; in the solvent historical unit, the asphaltene fraction, the historical oil fraction and the solvent fraction Separating water and salt from the fraction; and conveying at least a portion of the solvent fraction to the production site to dilute the heavy oil or bitumen and form the mixture. Including the degree. The method in this patent is of course limited to crude oils with two or more APIs (APIs in the range of 2-5 are claimed). This is because clogging of the extractor always results in low reliability and the conditions allowed in this process limit the overall yield to <85% of the total barrel. This is because heavy crude oils such as bitumen will have an asphaltene content of over 15%, and these molecules are completely eliminated by this method.

  U.S. Pat. No. 7,964,090 discloses a method for upgrading heavy asphaltenic crudes using SDA and gasification. What is interesting in this patent is that the stream to the gasifier is generated by mixing a solvent and a hydrocarbon containing one or more asphaltenes and one or more non-asphaltenic materials, where The solvent to hydrocarbon ratio is in the range of about 2: 1 to about 10: 1. The asphaltene rich stream is transferred from the SDA to the gasifier as a liquid stream. A large amount of solvent used in transportation is consumed in the gasifier and is downgraded to a value equivalent to fuel gas. Since the asphaltenes tend to be liquids, it is feasible to use a solvent for transporting the material in the stated amounts. For solid asphaltenes, this method will require 10-20 times more solvent for transportation, and such amounts of expensive solvent will be consumed and reduced in value.

In essence, an improved process for producing pipeline-ready crude oil and refinery feedstock from heavy crude oil such as Canadian oil sand bitumen is described, which process comprises the following steps: (1) Optimal asphaltene conversion with minimal coke generation and off-gas generation in complete bitumen flow in the reactor, thermally affected asphaltene-rich fraction, minimum amount of non-condensable Generating a vapor stream and a liquid stream of an increased amount of refinery feedstock; (2) subjecting the thermally-affected asphaltene-rich fraction to a history process to produce a refinery feed liquid stream and Concentrated asphaltene stream; (3) selectively hydrotreating certain hydrocarbon components as required for pipeline specifications and the above liquid Finally blending all of the streams to produce refinery feedstock; and (4) inertial separation of the concentrated solid asphaltene stream for conversion in a gasifier, power plant or asphalt plant. Process.
The bitumen is thermally treated to remove and convert / decompose selected asphaltenes, which are then sufficiently separated in a more efficient solvent extraction process, thus reducing coke formation and as desired. Isolate nuisance contaminants (metals, MCR, and residual asphaltenes).

Under the operating conditions of the present invention described herein, the side chains are preferentially cleaved from the central asphaltene molecule, taking into account the relative complexity and high side chain ownership of Canadian bitumen asphaltenes. Thus, the desired vacuum gas oil is used as a component of the light hydrocarbon region. Residual thermally affected polyaromatic asphaltene cores maintain a solid state at high temperatures and pressures above operating conditions, thus improving solvent desaturation (50) and inertial separation ( 60 ), etc. Is more easily separated than the thermally unaffected asphaltenes that occur in the separated separation processes.
In addition, the heavier hydrocarbons in the bitumen are also gently broken down into the components of vacuum gas oil, gasoline and effluent boiling regions that are all desirable for separation and conversion in refineries. Any major deviations in temperature and heat flux within the bitumen pool in the reactor will lead to coking and high gas yields, as well as a reduction in the overall crude yield of the original bitumen, and low reliability of the operation. Which increases the operating costs of this equipment.

The present invention provides pipeline-ready and refinery-ready feedstocks from heavy, high asphaltene crudes (e.g., Canadian bitumen) and feedstocks that have utility as untreated or pretreated hydrocarbon streams. An apparatus and method for manufacturing is provided, the method and apparatus including a preheating device for preheating the process fluid to a desired operating temperature of the reactor or a design temperature in the vicinity thereof; Applying heat while adjusting the process fluid in a reactor for converting the fluid to transfer the fluid into the reactor for converting the fluid, resulting in the reaction of the process fluid to the reaction Maintain a substantially uniform temperature throughout the vessel, containing a stream of fractions rich in thermally affected asphaltenes and a minimum amount of non-condensable vapor A liquid hydrocarbon vapor stream is generated. The steam stream is separated into two further streams: a non-condensable steam and a light liquid hydrocarbon stream. The thermally affected fractions rich in asphaltenes are first mixed using a high shear mixer, then dehistorized using a one-stage solvent extraction method, respectively, and then reconstituted oil liquid and concentrated. Made asphaltene. The historic oil liquid and light liquid hydrocarbons produced in these processes are blended into pipeline-ready and refinery-ready feeds. The concentrated asphaltenes are processed in an inertial separation unit to produce dry solid asphaltenes by-products.
A sweep gas can be placed in the reactor and can be preheated to provide a heat flux source other than the heater of the reactor, the sweep gas also containing vaporous product in the reactor. May help with removal.

The history is achieved using at least one extraction stage (more stages can be used) and a low pressure stripper at conditions other than any published technology solvent extraction methods. Since the initial process fluid is thermally affected, the heavy asphaltene rich fraction is a lower solvent than that typically found in high shear mixers and similar upgrader operations. Further separation can be achieved using a less complex one-stage extraction method using a combination of oil to oil ratio, temperature and pressure. Further improved solvent-extraction performance and improved DAO yields using a lower overall solvent to oil ratio, further enriching the asphaltene rich fraction prior to final extraction step This can be achieved. This method provides an improvement over the published solvent history method by using an additional solvent extraction column (rinse column) operated on the asphaltene rich stream from the first solvent extraction column, Increase recovery and quality of pipeline crude.
The SDA process allows some portion of the heavy asphaltenic hydrocarbon stream to be recycled to the reactor and blended with fresh feedstock.
The resulting concentrated thermally affected asphaltenes can be successfully processed in an inertial separation unit such as a centrifugal collector or a sedimentation chamber to produce dry solid asphaltenes by-products.

  Referring to the accompanying drawings, wherein like reference numerals designate like parts throughout the several views, several aspects of the invention in these drawings do not limit the invention. This is illustrated in detail.

FIG. 1 is a process diagram for producing a pipeline transportable hydrocarbon product derived from a heavy hydrocarbon feedstock. FIG. 2 is a process diagram specifically related to the decomposition process, the liquid separation process, and the solid separation process. FIG. 3 shows an exemplary application of an integrated mild pyrolysis method and an improved solvent devolatilization method, in which a vacuum and / or according to one or more of the described embodiments is provided. Alternatively, use an existing upgrader equipped with a caulking unit or a shear mixing device suitably placed in a refinery. FIG. 4 illustrates a specific exemplary application of the integrated mild pyrolysis method and improved solvent desaturation method that differs from FIG. 3 and includes one or more of those described herein. A vacuum residue from an existing upgrader or refinery containing various products from the integrated cracker / SDA sent to a hydrocracking, residue hydrocracking and gasification unit according to the above embodiment. A liquid stream is supplied.

The detailed description set forth below in connection with the appended drawings is intended as a description of various aspects of the invention and is not intended to represent the only aspects contemplated by the inventors. This detailed description includes specific details for the purpose of providing a comprehensive understanding of the present invention. However, it will be apparent to those skilled in the art that the present invention may be practiced without these specific details.
It should be understood that other aspects of the present invention will be readily apparent to those skilled in the art from the following detailed description, wherein various embodiments of the invention are shown in the following detailed description, It is also described as an example. As will be appreciated, the invention is applicable to other and different aspects, and several details thereof may be found in various other forms without departing from the spirit and scope of the invention in any way. Improvements can be made in this respect. Accordingly, the following drawings and detailed description are to be regarded as illustrative in nature and not as restrictive.

FIG. 1 is a process flow diagram depicting a method 10 for producing a hydrocarbon product 160 from a hydrocarbon feedstock 12, where the final hydrocarbon product 160 is a minimum pipeline transportation requirement. It has sufficient properties to meet (minimum API specific gravity of 19) and is a convenient refinery feedstock. The process fluid 14 formed from the heavy hydrocarbon feedstock 12 can be delivered through a heater 20 for heating the process fluid 14 to a predetermined temperature level before delivery to the reactor 30; In the reactor, the process fluid 14 is controlled and maintained, while it is subject to a mild controlled cracking process. After the mild decomposition step, the light top fraction 32 can be delivered from the reactor 30 to the gas-liquid condensation separation step 40 and the heavy residual liquid fraction 34 is sent to the high performance solvent extraction step 50. Can be delivered to. Some of the product 44 from the gas-liquid separation process 40 may be blended with some of the products 52, 54 of the high performance solvent extraction process 50 to form a hydrocarbon product 160, The product can be produced in the required pipeline without the need to mix the final hydrocarbon product 160 with diluent from an external source, or without the need for such a reduced volume of such diluent. It has enough physical properties to make it possible to meet transportation standards.
The feedstock 12 is a heavy hydrocarbon (untreated or pre-treated stream), such as a heavy hydrocarbon obtained from a SAGD (steam assisted gravity drainage) process, such as Canadian oil sand bitumen, or heavy It can be a heavy hydrocarbon derived from any other suitable source of hydrocarbons. In one aspect, the feedstock 12 can have an API specific gravity in the range of 0-14.

In one aspect, the recycle portion 70 of the resin stream 54 as a product derived from the high performance solvent extraction step 50 is used to produce the process fluid 14 flowing through step 10, Can be blended. The resin stream may be used in instances where further crude oil yield and / or lighter crude oil, and / or asphaltene removal (suppression) is desirable to meet the target characteristics of the processed product. It can be added to the process fluid. The resin recirculation provides flexibility to the operator through adjustable flow parameters to meet manufacturing specifications and allows the plant to actively handle a variety of feedstocks. To do.
The resin product 54 from the solvent extraction step 50 will typically have a relatively low API specific gravity. In one aspect, the API specific gravity of the resin product 54 can have an API specific gravity in the range of 0-10. Depending on the properties of the feedstock 12 and the amount of the product 54 blended with the feedstock 12, the resulting process fluid 14 can have a range of properties and in particular a range of API specific gravity.

The process fluid 14 (completely obtained from the feedstock 12 or made as a blend of the feedstock 12 and the resin product 54 from the solvent extraction step 50) is delivered to the heater 20. In the heater, the process fluid 14 can be heated to a predetermined temperature as it passes through the heater 20 before being delivered to the reactor 30 and subjected to mild pyrolysis. Reactor 30 maintains coherent fluid temperature by applying heat uniformly throughout the reactor, resulting in coking that is problematic or detrimental to the operation and / or performance of the reactor. Allows mild pyrolysis to occur without causing
In one aspect, the heater 20 heats the fluid 14 to a temperature in the range of about 357 ° C. to about 413 ° C. (675-775 ° F.) prior to introducing the process fluid 14 into the reactor 30. Will.
In the reactor 30, the process fluid 14 (heated to a temperature in the range of about 357 ° C. to about 413 ° C. (675-775 ° F.) by the heater 20) is subjected to a mild and controlled decomposition step. It is done. The reactor 30 is provided with a suitably arranged heater so as to maintain the desired constant temperature generated in the heater 20 and to apply a uniform heat flux to the process fluid 14. . These heaters supply heat via any readily available source (electrical machine, heat transfer fluid, illuminant, etc.). The reactor 30 mainly reduces or even prevents coke formation during the reaction through optimization of five interrelated process variables (temperature, pressure, residence time, sweep gas and heat flux). It can be operated and also minimizes gas production and results in optimal conversion of a portion of the heavy hydrocarbon asphaltene portion to a refinery-ready feedstock component.

The first and second variables are processes in the reactor with a uniform heat flux ranging from about 2.21 × 10 ⁴ to about 3.79 × 10 ⁴ W / m ² (7000-12000 BTU / hour · ft ² ). Application to the entire pool of fluids and maintenance of a single operating temperature in the reactor in the range of about 357 ° C to about 413 ° C (675-775 ° F). This can be achieved by the presence of an appropriately sized and properly arranged heating device in the reactor. The number of heaters allows the optimal distribution of heat between any two heaters to have a uniform temperature across the pool, and to generate a peak or spot temperature that is significantly higher than the target temperature in the reactor. Would be set by calculating to avoid
The third reactor variable, dwell time, can be a value in the range of 40-180 minutes in the reactor.
The fourth reactor variable, operating pressure, is a pressure near atmospheric pressure of less than about 0.345 MPaG (50 psig) in all cases, using standard pressure regulation principles used to achieve consistent performance. Can be maintained. This pressure range is adjusted to the low pressure limit essentially by bypassing the reactor to prevent excessive and premature flushing of hydrocarbons, and secondary cracking and consequent In order to reduce the high gas yield, it is limited to the above high pressure limit.
The fifth reactor variable, the hot sweep gas 36 in the same temperature range [about 357 ° C. to about 413 ° C. (675-775 ° F.)] as the process fluid 21, is about 0.36 to about 1.44 kJ / L (20-80 scf / bbl) is added to the process fluid 14 in the reactor 30.

The sweep gas 36 can be natural gas, hydrogen, product / fuel gas from the above process, steam, nitrogen or any other non-reactive, non-condensable that does not condense into a liquid in the reactor environment. It can be a sex gas.
The sweep gas at doses ranging from about 0.36 to about 1.44 kJ / L (20-80 scf / bbl) of the feedstock is the above “lighter” hydrocarbon product (ie, methane to <about 399 ° C. (< Hydrocarbons with a boiling point of 750 ° F.) are removed as soon as they are produced in the reactor 30 and fed to minimize secondary cracking. Cracking can increase gas generation and possibly increase olefinic naphtha / distillate production.
The sweep gas also allows the reactor to operate near the desired operating pressure [less than about 0.345 MPaG (<50 psig)] and operating temperature. The sweep gas 36 may also supply additional heat and / or mix with the process fluid 14 in the reactor 30.

As discussed above with respect to FIGS. 1 and 2, the thermal energy flow 36 to the reactor 30 is the desired temperature [about 357 ° C. to about 413 ° C. (675-775 ° F.)] and pressure [less than about 0.345 MPaG. (Less than 50 psig)] uniformly [about 2.21 × 10 ⁴ to about 3.79 × 10 ⁴ W / m ² (7000-12000 BTU] throughout the residence time of the hydrocarbon in the reactor (40 to 180 minutes) / hr · ft ²⁾ scope] is applied to minimize the occurrence of peak temperature of any local fluid that could initiate coking, thereby improving the conversion of hydrocarbons in the reactor 30 Enables high heat conduction at higher internal temperatures. Under these operating conditions, the rate of the reaction favors the optimal conversion of the asphaltenes, which does not cause coking in the reactor or results in high gas production. It preferentially cleaves hydrocarbon chains outside the predetermined range to produce the desired hydrocarbon for purification (VGO and diesel range hydrocarbons). As an example, Table 1 below shows various shapes and configurations of asphaltenes associated with various types of crude oil. The proposed reactor 30 operating conditions take into account the high side chain abundance and relative complexity for a variety of different crude oils.

Table 1: Average molecular structure representing asphaltene molecules from various sources: A: Asphaltenes from traditional heavy crudes; B: Asphaltenes from Canadian bitumen (Sheremata et al., 2004).

Each variable can be varied independently within the suggested range based on the quality of the feedstock provided or based on the desired product quality. Because the above five described process variables are interrelated, a multi-variable process control scheme with a predetermined target function (e.g., maximum yield to meet minimum product specifications) is It would be beneficial to ensure that the method operates at an optimal point if any one of the variables is changed or if the feed / product status or goal is changed.
Once the process fluid 14 has been maintained in the reactor 30 for a sufficient period of time so that the product characteristics from the reactor 30 reach predetermined properties, the light overhead fraction 32 and heavy The residual liquid fraction 34 can be removed from the reactor 30.
The light overhead fraction 32 of the product originating from the reactor 30 can include non-condensable vapor products, light liquid hydrocarbons and heavier liquid hydrocarbons. The steam product may be steam released from the process fluid 14 while undergoing pyrolysis, such as sour gas, as well as introduced and unconverted or unused sweep gas 36 circulated through the reactor 30. .

The overhead liquid fraction 32 will have a greater API specific gravity than the residual liquid fraction 34. For example, the overhead liquid fraction 32 can typically have an API specific gravity of 26 or more. The overhead fraction 32 can be directed to a gas-liquid separation unit 40, which can include, as an example, a cooler 41 and a separation drum 42, where a condensable liquid containing naphtha and heavy hydrocarbons. A portion of the overhead fraction 32 that is product can be separated from the gaseous components of the overhead fraction 32. An off-gas line 43 containing undesired gases, such as sour gas, allows the separation drum 42 to dispose of these gases, recirculate them, or subject them to further processing.
One or more liquid hydrocarbon streams can be produced by the separation drum 42. Consider hydrocarbons that are heavier than stream 44, or stream 46, to the product blending process, while stream 46 is subjected to a larger hydroprocessing prior to product blending. You can also.
The residual liquid fraction 34 can contain hydrocarbons and modified asphaltenes. The characteristics of the residual liquid fraction 34 collected from the reactor 30 vary depending on the input amount of the process fluid 14 to the reactor 30 and the operating parameters of the reactor. The liquid fraction 34 can have an API specific gravity in the range of -7 to 5.

Adjustable process variables allow the operator to change the performance of the reactor 30 to meet the requirements of the final product based on changes in the characteristics of the incoming process fluid 14.
The controllability of the five interrelated variables in the reactor 30, the residence time, sweep gas, heat flux, temperature and pressure, allows the operator to change the performance of the reactor 30. To do.
Thus, when the characteristics of the feedstock 12 are changed as either a different new feedstock or some resin recirculation 70, the five interrelated process variables are responsible for coke formation. And can be optimized to minimize the production of non-condensable vapors produced in the reactor 30. For example, the operator can change the residence time of the process fluid 14 in the reactor 30 based on the characteristics of the process fluid 14 to obtain the desired yield and / or quality of the products 32, 34. Can do. Alternatively, the operator can change the sweep gas, temperature or pressure to achieve a similarly adapted result. These process variables are interrelated, minimizing coke generation and avoiding excessive gas production are attractive, and these are best determined by pilot operations, which are determined by excessive experimentation. Can be done without.

The residual fraction 34 from the reactor 30 can be fed to a high performance solvent extraction step 50, which comprises a thermally affected asphaltene stream 58, an extracted oil stream. 52 and resin stream 54 can be produced. The reactor 30 is operated to significantly limit and further inhibit coke formation, reduce gas production, and convert asphaltenes to more suitable components for downstream processing. As a result, modified asphaltenes and other unwanted elements are left in the residual fraction 34 and the fraction is removed from the reactor 30.
In order to maximize the recovery of crude oil as the desired refinery feedstock, which does not include the undesirable elements left in the residual liquid fraction 34, the residual from the reactor 30. The liquid fraction 34 needs to be further processed using, for example, a high performance solvent extraction step 50. The treatment of the residual fraction 34 by the solvent extraction step 50 is to use the reactor 30 and the solvent extraction step 50 in combination to produce crude oil as a suitable full range refinery feedstock. Make it possible.

The solvent extraction step 50 can include any suitable solvent extraction step. In one aspect, the method can be a three-stage supercritical solvent method, which separates the asphaltenes from the resin in the residual fraction 34. The product of the solvent extraction step 50 can be an asphaltene stream 58, an extracted oil stream 52, and a resin stream 54. The asphaltene stream 58 is typically not desirable and is removed from step 10. The extracted oil stream 52 can be of relatively high quality and has an API specific gravity in the range of 9-15. The resin stream 54 is typically of lower quality than the extracted oil stream 52 and has a lower API specific gravity than the extracted oil stream 52. In one aspect, the resin stream 54 can have an API specific gravity in the range of 0-10 API specific gravity.
The extracted oil stream 52 and the resin stream 54 from the solvent extraction step 50 are blended with the liquid product stream 44 obtained from the gas-liquid separator 40 to produce a pipeline and / or refinery-ready. A final hydrocarbon product 160 that satisfies the specification value can be produced. In one aspect, this final hydrocarbon product 160 will have an API gravity greater than 19. Typically, the final hydrocarbon product 160 will have a viscosity of 350 centistokes (cSt) or less.
The resin stream 54 is typically of lower quality than the extracted oil stream 52. The recycle portion 70 of the resin stream 54 can be blended with the feedstock 12 to be reprocessed to produce the final hydrocarbon product 160. As a result, this recycle portion of the resin stream will improve the quality of the final hydrocarbon product 160.

In another aspect in FIG. 2, when integrated with reactor 30, operated using the above five interrelated variables, and thus operated to achieve maximum yield. The optimal solvent desaturation and solid separation schemes are illustrated. A shear mixer 25 and a single asphaltene extractor 50 are provided to separate solid asphaltenes in stream 58 from the oil and solvent stream 51. Due to the thermally affected asphaltenes produced in the reactor 30, the solvent extraction occurs in one stage and at a solvent to oil mass ratio of up to about 2.5: 1 and the solvent Can be effective at operating conditions well below the critical point. As a result of the low energy / intensity one-stage extraction, a single low pressure solvent stripper process stream 41 is economical in separating the historical oil 52 as the product and the recovered solvent as the stream 101. And effective. Stream 58, ie the concentrated asphaltene solid stream, is processed in an inertial separation unit 60 that separates solvent vapor stream 62 and dry solid asphaltene stream 61. Stream 62 is concentrated at 110 and the solvent is recycled for use in the above process. The dry solid is sent to a dry solid storage tank 130 or otherwise processed. The inertial separation unit 60 uses a combination of forces such as centrifugal force, gravity, and inertial force to separate the asphaltene solid from the gas in the stream 58, residual solvent. These forces allow the asphaltene solid to be transferred to an area where the force exerted by the gas stream is minimal. The separated solid asphaltenes can be transferred by gravity to a hopper that temporarily stores the solids. Unit 60 can be either a sedimentation chamber, a baffle chamber or a centrifugal collector, a device that provides an inertial separation of solids and gases. The centrifugal collector can be either a 1-stage or a multistage cyclone. If the SDA unit 50 is extremely effective in separating the asphaltenes from the resin, DAO and solvent, stream 58 uses a suitable low molecular weight gas (e.g., natural gas or nitrogen). To provide gas conveying means to the asphaltene solid, which would otherwise be supplied by flushing residual process solvent in the line. The gas delivery system can transport solids up to about 50 mm particle size. The solid must be dry and contain no more than 20% moisture and be non-tacky. The thermally affected asphaltene solid satisfies the above criteria, and thus the method benefits from the ability to use the inertial separation unit 60 .

In order to increase the overall recovery of the product hydrocarbons from the reactor 30 and reduce the solvent circulation rate, the high performance solvent extraction process 50, along with another shear mixer 235, is optionally supplemented. An extraction processing step 55 can be included. The additional solvent extraction step for the asphaltene-rich stream by the second extractor 55 utilizes standard liquid-liquid extraction using the same solvent as used in the first extractor. To do. The placement of this standard liquid-liquid column for the asphaltene rich stream can be beneficial because its solvent to oil ratio is economically increased to 20: 1 in this column, resulting in This is because the recovery rate of the history oil is increased while the overall solvent usage is reduced. The overall solvent usage to achieve high hydrocarbon recovery in stream 52 can be 25% lower than using comparable published technology methods. The result is a significant savings in energy consumption compared to state-of-the-art 3-stage extraction methods. The resulting asphaltene stream 58 may be processed in an inertial separation unit 60 that separates asphaltenes that are 20% smaller. The remaining concentrated, the core portion of the asphaltenes subjected to thermal effects are solid even at a high temperature [about 371 ℃ (700 ° F)] , side hydrocarbon chains have been removed, the inertial separation unit Makes the volume to be processed smaller. In addition, the improved properties of the asphaltenes are due to more effective metal regeneration, landfill and clean energy conversion technologies (e.g. gasification, catalytic gasification, oxy-combustion for enhanced SAGD production) ) Provides an opportunity to get a better feedstock for.

  Step 10 in FIG. 1 provides a crude feedstock that meets pipeline requirements and is optimal for high conversion refineries. Stream 160 has low metal (<20 wppm Ni + V), low asphaltene (<0.3 wt%), very low TAN number (<0.3 mg KOH / mg), no diluent, and VGO range material Is high (30-50% of crude oil). For high conversion refineries (> 1.4: 1 conversion to caulking), the distillation grade of crude oil produced in stream 160 is the highest profit-generating unit while filling the remaining units. Will improve the usability. In Table 2 below, the percentage of material in each boiling range, including oil 159L (1 barrel) as a variety of representative heavy oil crude streams, is shown compared to stream 10 of step 10. “Non-upgraded” feedstock (dilbit = diluted bitumen; WCS = Western Canada Select) requires strong conversion, more than 35% of total barrels, more vacuum Lighter substances (C5's) that contain heavy residues [substances of about 510 + ° C (substances of 950 + ° C)] and should be transported to refineries rather than refiners can be advantageously refined into transportation fuels . On the other hand, the fully upgraded / manufactured refinery-ready feedstock (SSB = sweet synthetic blend) is essentially free of vacuum residue or light matter (C5's). This is unbalanced and therefore has a volume limit for the refiner. Oil refiners have 10-25% vacuum residue, 20-50% gas oil (HVGO = heavy vacuum gas oil, LVGO = light vacuum gas oil, AGO = atmospheric pressure gas oil), 40-60% gasoline An operation has been developed to process feedstock that is generally well balanced, including materials in the to diesel range. As shown in Table 2 below, stream 160 has other heavy conventional well-balanced crude oils having a hydrocarbon composition that is in the same range as other heavy known crude oils [ ANS = Alaska North Slope, WTI = West Texas Intermediate, MSO = Medium Sour (Midale)].

The combination of reactor 30, high performance solvent extraction processing unit 50, and inertial separation unit 60 exhibits low process complexity. This can be expressed as a Nelson complexity index value of 4.0-4.5, substantially lower than 9.0-10.0 for coking and / or hydroprocessing schemes. Another example of improved performance is the low energy of 3.93 GJ / ton (feed) compared to a delayed coking process that requires an energy input of 4.70 GJ / ton (feed) to operate. It is a request amount. This represents a 16.4% reduction in energy intensity compared to the delayed coking method. This is a specific greenhouse gas (GHG) emissions of 0.253 ton CO ₂ / ton (feed) for the delayed coking process and 0.213 ton CO ₂ / ton (feed) for the proposed method. It corresponds to. Based on product comparison, the energy reduction is about 25-27% for the coking process.
Step 10 minimizes the production of by-products (coke and non-condensable hydrocarbons) as described in Table 3 below when compared to the coking upgrade method and standard reactor and solvent extraction methods. Provides a significant improvement in yield.

  Another benefit that can be attributed to lower operating temperatures and pressures due to the low complexity of step 10 is lower capital cost invested. The flange rating that requires less equipment and can be used is a “break-point” where the material specifications change due to the associated temperature and pressure, resulting in increased costs. It is far below. Considering the high sulfur content of the material and the TAN rating, 304L / 316LSS material is an appropriate choice for reliability. For this metallurgy, as an example, Class 300 pipes and flanges can handle up to about 204 ° C (400 ° F) and about 2.86 MPaG (415 psig) (origin: ASME / ANSI B16.5 1988/2009 standard). . The SDA unit operates at a maximum of about 204 ° C. (400 ° F.) and about 2.76 MPaG (400 psig), and can therefore identify Class 300. Compared to the open technology SDA process, higher grade pipe / flange classes, such as class 600, will require treatment at higher operating temperatures and pressures than these other processes. The overall investment cost savings for the class 600 flange is 20--for the step 10 versus the published technology SDA configuration process, which costs eight times the price of the class 300 flange, for example. It will be in the range of 30%.

While suitable for a new mass installation, FIG. 3 discloses the disclosed pyrolyzer of the present invention and an improved SDA to an existing upgrader. An example of application is shown. The proposed integrated method, reactor 30, simplified SDA 50, and inertial separation unit 60 to recover asphaltenes may be located upstream of the refinery / upgrader coking unit. The benefit for the refinery / upgrader is the ability to eliminate the obstruction of the vacuum and coking units and the ability to accept heavier crude oil for the units. The greater amount of crude oil processed with existing equipment matches invested capital with greater profits and economic returns. In addition, because higher performance materials are sent to the caulking unit 300, the severity of operation can be reduced, and the life of the caulking device can be increased by increasing the cycle time (12-24 hours) of the caulking device. Extended and less gas and coke and higher product is produced. Expenditure on the cost of capital for equipment replacement can be postponed and high yields can be achieved (approximately 2-3%). The solid asphaltenes captured in the SDA include a readily available disposal stream 302, and existing coke collection and transport systems are more cost effective to add the proposed integrated method. And higher profit margin.

Stream 12 can be a residual stream from an asphaltene column, vacuum column, or catalytic cracking unit, as described as unit 200 in FIG. The integrated cracker and SDA process produce a DAO stream 52 that is further processed in a combined hydrocracking and hydrotreating unit 400 to provide transport fuel for stream 401. Can do. The integrated cracker and SDA process also produces coking FCC (fluidized bed catalytic cracking) and / or a resin grade stream 54 that can be further processed and sent to an asphalt plant for final product. obtain. As previously mentioned, the solid asphaltenes produced as stream 61 are mixed with the coke produced in unit 300, or remote locations for further processing (energy production and / or sequestration). Can be sent to.
As an example, FIG. 4 illustrates a particular embodiment that provides an opportunity to newly design or improve a refinery and / or upgrader. Unit 200 is a vacuum unit, also the residual liquid stream 12 is integrated cracker / SDA process, sent units 20, 30, 40, 50, and 60. The DAO stream 52 is sent to the hydrocracking and hydroprocessing unit 400 along with stream 205 from the vacuum unit. Resin stream 54 is produced by unit 50 and sent to residue hydrocracking unit 500. If the reaction is remarkably exothermic and less asphaltenes are sent to unit 500, the residue hydrocracking unit can operate at higher conversions (+ 8-15%) for final transport. Produce more material as a fuel product. The solid asphaltene stream 61 from unit 60 can be sent to a gasification unit for hydrogen generation.

As in FIG. 3, the benefits of adding an integrated unit as shown in FIG. 4 include those listed below: If present, the maximum yield of incoming crude oil for plant debottlenecking Reducing the rate or size of the coking unit; eliminating obstacles if present or reducing residue hydrocracking size; eliminating obstacles if present or reducing the size of the gasification unit; Reduced overall carbon footprint.
The integration process of Figure 2 also helps the use of less expensive, heavy, cheaper crude oil to be handled by a less complex (hydro-skimming) refinery that is easier to handle. As a result, useful items are moved to obtain more consideration. The integration process is located in front of the refinery and allows for the initial conditioning of the heavier crude oil.

(Comparison of operating conditions)
The novel arrangement and features of the above integration process according to the present invention can provide an opportunity to operate in areas that were previously not possible with any particular known art method, thereby making heavy hydrocarbons Create a technically feasible and economically advantageous solution for processing up to 0 API values. This low complexity integration process, resulting in low operating costs and capital costs with volume yields from DAO ranging from 89-91% and solvent losses below 2%, is pipeline-ready and refinery Create an economic (revenue-based) solution for producing commercial feedstock. Table 4 below provides a comparison of some representative existing patents with the present invention. Items indicated by bold lines represent conditions that directly limit the known technique or make the known technique disadvantageous when compared to Step 10. None of the comparison techniques achieves yields similar to the exemplified method for heavy hydrocarbon feedstocks in the range of 0-7 API specific gravity. This comparison includes an integrated disassembly device and SDA unit, and even an SDA-only scheme. The present invention borrows some concepts relating to the pyrolysis process outlined in US Pat. No. 7,976,695 for some of its operations, so no comparison with the pyrolysis process is given. . As shown in Table 4, the unique combination of operating conditions of the pyrolyzer allows the SDA to be simplified, and the SDA is an inertial separation that strictly handles the operating conditions and asphaltene solids and solvent vapors. It can operate by a unique combination with the use of the unit .

  Using this integration process, crude oil in the API range of 0-12 + can be processed with high reliability. Further, the SDA unit 50 can accept a feedstock having an API in the range of -5 to 0 with high reliability. The use of the above sweep gas (not used in other similar methods), uniform heat flux (not maintained uniform in other methods), low operating temperature and pressure makes the mild and convenient reaction It is possible to change to a gas oil in this range, suitable for pipeline transportation with existing hydrocarbons that fall in the range of light gas oil. The lowest coke production and light gas production maintains the majority of the hydrocarbons (> 90% of the crude barrel) as the desired product. In addition, asphaltenes have been converted from “sticky” molecules to “crunching” molecules. The improved asphaltene rich stream with an API density in the range of -7 to 0 can be processed in a simplified SDA process using a novel combination of operating conditions. A low pressure solvent stripper equipped with a single extraction stage and an inertial solids separator is all that is needed to obtain the high yields described above. As shown in Table 5 below, the solvent to oil mass ratio can be in the range of 2-4: 1 for the preferred solvent in the range of C6 to C7. The temperature in the single extraction column is well below its critical value, as is its pressure. At these low operating conditions, the energy used is greatly reduced and only a single low pressure stripper is required. A very small number of physical equipment with less expensive materials and construction is required, which makes the overall cost of investment lower than other concepts.

In order to be technically feasible while meeting the economic choices of the solvent, the solvent used to escape heavy crude oil (less than 2 API) would just precipitate the required asphaltenes, and the DAO. Must be sufficiently heavy (having a sufficiently high molecular weight) to be kept in solution by the solvent. Also, the solvent needs to be light enough to be flushed during transfer of the asphalt extractor liquor (solid asphaltene + solvent) without requiring a large amount of energy. Similarly, the operating temperature should be low enough to increase the solubility of DAO in the solvent, and there should be sufficient heat for the solvent to flush during the transfer of the solid asphaltenes. Need to be high enough. Because of this process, the precipitation of solid asphaltenes from solution has little effect on the choice of solvent. Table 5 provides a comparison of solvents to consider when processing heavy and viscous hydrocarbons (-7-0 API to SDA above). The C6 and C7 give high yields (89-91%) and the low complexity of the method yields a new and economically feasible method.

  Based on the similar effectiveness of C6 and C7 solvents for separating asphaltenes, blends of these hydrocarbons can be considered to reduce costs. An approximate fraction of the transfer diluent can be withdrawn and can be considered for use as a solvent in the SDA. Testing can be a low-cost option when a mixture of C5-C8 (> 60% C6 and C7) is charged with the solvent for operation in step 10 above. This further reduces the operating cost of the process through the purchase of readily available solvents, which are usually characterized as feed diluents for the process.

  The previous description of the above disclosed aspects is provided to enable any person skilled in the art to make or use the present invention. Various modifications to these embodiments will be readily apparent to those skilled in the art, and the general principles defined herein may be used without departing from the spirit and scope of the invention. It is possible to apply to the aspect of this. Accordingly, the invention is not intended to be limited to the embodiments shown herein but is to be accorded the full scope consistent with the claims, expressed in the singular in the claims. An element, for example an element indicated by the use of the indefinite article “a” or “an”, does not mean “one or only one” unless stated otherwise, rather than “one or more”. Shall mean. Various elements described throughout the present disclosure and all structurally and functionally equivalent elements known to those skilled in the art or later known to those skilled in the art are claimed in the claims. To be included in these elements. Moreover, nothing in this specification intends to disclose that such disclosure, whether or not explicitly stated in the claims. Yes.

(Glossary of terms used in this application)
The applicant will provide the following explanation to assist the reader in explaining the patent application. Of course, these definitions do not replace the common and general meanings of these terms, as will be understood by those skilled in the art of the present invention, and are meant to be auxiliary means; When there are two or more meanings for a similar term, it means to remove the ambiguity.
Asphaltenes : Asphaltenes are insoluble in n-propane (or n-heptane) at a dilution ratio of (1) 40 parts alkane to 1 part crude and (2) redissolved in toluene. It is a substance.
Bitumen : Shares the attributes of heavy oil, but is still dense and viscous. Natural bitumen is an oil with a viscosity greater than 10,000 cP and an API typically <10.
Residual liquid : Crude oil material that does not evaporate in the thermal decomposition apparatus. Mainly consists of gas oil, resin and asphaltenes.
Canadian bitumen : Crude oil with an API gravity of <10, sourced from Canada.
Canadian heavy crude : It consists of both conventional heavy oil and bitumen with an API of <20.
Detached oil (DAO) : A heavy oil portion containing the majority of the extracted asphaltenes with a nominal boiling range of 260 + ° C (500 + ° F).
Gas oil : An arbitrary portion of crude oil that boils in the range of 271-538 ° C (520-1000 ° F).

Heavy oil : This is an asphalt-like, high-density (with low API specific gravity <20 API) and viscous oil (limit of 100 cP), which is chemically characterized by its asphaltene content ( A very large molecule that incorporates most of the sulfur in the oil and possibly 90% of the metal).
Light end : A hydrocarbon of 5 carbon chains and below, typically including pentane, pentylene, butane, butylene, propane, propylene, ethane, ethylene and methane. Includes all substances found in crude oil and bitumen with boiling points below 37.8 ° C (100 ° F) at atmospheric conditions.
MCR : This is a microcarbon residue.
Resin : A heavy oil portion that is in the boiling range of 427 + ° C (800 + ° F) and can contain asphaltenes.
SDA : This means “solvent historyr” or “solvent historyr” and typically also refers to the SDA unit, which unit removes asphalt from the process fluid using a solvent. Processing device (or stage).
Syngas : A gaseous mixture composed primarily of pollutants generated by the destructive distillation of hydrogen, methane, carbon monoxide, and hydrocarbons.
Top crude : A stream of crude oil left after removing a significant amount of the more volatile components of crude petroleum (eg, light end) by distillation or other means. part.
Preferred embodiments of the present invention are as follows.
[1] Optimized and integrated to produce pipeline- or refinery-ready feeds and dry, thermally affected asphaltene solids from heavy, high asphaltene feed process fluids Wherein the method comprises the following steps:
(a) preheating the process fluid in a heater to a designed temperature;
(b) transferring the preheated process fluid to a reactor and optimally converting the asphaltenes in the process fluid in the reactor to form a first fraction comprising a thermally affected asphaltene rich fraction. Producing a stream and a second stream of steam;
(c) separating the second stream of steam into a third stream of non-condensable steam and a fourth stream of lighter liquid hydrocarbons;
(d) the asphaltene-rich fraction affected by the heat of the first stream is desaturated by a solvent extraction method to obtain a fifth stream consisting of heavy, de-histored oil (DAO) and Making a sixth stream of concentrated asphaltenes;
(e) blending the fifth stream of heavy DAO and the fourth stream of liquid hydrocarbons into the pipeline- or refinery-ready feed; and
(f) The sixth stream comprising the concentrated asphaltenes, in the inertial separation unit, in the dry state, the seventh stream comprising the solid asphaltenes and the eighth stream comprising the solvent for reuse in the process. The process of separating into streams.
[2] The process according to [1] as a continuous process, wherein the reactor is a single thermal conversion reactor equipped with an overhead condenser operating within the following parameters:
(a) a uniform heat flux in the range of about 2.21 × 10 ⁴ to about 3.79 × 10 ⁴ W / m ² (7,000 to 12,000 BTU / hr · ft ² ) introduced into the process fluid in the reactor ;
(b) introducing a sweep gas of about 0.57 to about 2.27 m ³ / about 0.16 m ³ (20-80 scf / bbl) (gas / process fluid) into the reactor;
(c) residence time of the process fluid in the reactor for 40 to 180 minutes;
(d) a substantially uniform operating temperature in the reactor of from about 357 ° C to about 413 ° C (675-775 ° F);
(e) Near normal operating pressure in the reactor, <0.35 MPaG (<50 psig).
[3] The process according to [1] above as a continuous process, wherein the solvent history is a shear mixer, a simple asphalt extractor and a low pressure DAO / solvent recovery stripper operating with the following parameters:
(a) a solvent in the range of C6-C7;
(b) solvent to oil mass ratio in the range of 2-4: 1;
(c) critical temperature of the solvent-asphalt extractor operating temperature ranging from about 22.2 ° C (-40 ° F) to about 72.2 ° C (130 ° F);
(d) Critical pressure of the solvent—asphalt extractor operating pressure ranging from about 0.28 MPaG (−40 psig) to about 1.65 MPaG (240 psig).
[4] The method according to [1], wherein the step (f) uses an inertial separation unit.
[5] The feedstock sent to the method has an API in the range of 0-12, the feedstock to be sent sent to the solvent devolatilization step has an API in the range of -8-0, and The process of [1] above, wherein the resulting feedstock sent to the inertial separator is a solid at a temperature above about 371 ° C (700 ° F).
[6] The method according to [1] above, wherein the solvent is a part of a diluent (in the range of C ₅ -C ₈ ) used to transport the bitumen feedstock to the site .
[7] The high shear mixing treatment is performed on the flow between the SDA preheater and the SDA unit, or the flow between the first SDA unit and the second high solvent strength SDA unit. the method of.
[8] Pipeline-ready or refinery-ready feed from heavy hydrocarbons using a high performance solvent extraction process using a high local solvent to process fluid ratio while still maintaining a low overall solvent to process fluid ratio A process for producing a feedstock, first subjecting a heavy hydrocarbon to mild pyrolysis and then separating the asphaltene-rich fraction from the resulting thermally affected fluid to produce the high solvent of the process A method in which a portion having an oil to oil ratio is allowed to act only on these asphaltenic fractions and a dry solid asphaltenes is produced as the final product.
[9] The heavy hydrocarbon treatment to separate an asphaltene-rich fraction for extraction treatment, wherein the heavy hydrocarbon is placed in a process fluid and the process fluid is heated to a predetermined temperature; The process fluid is transferred to the reactor and at least one of temperature, residence time in the reactor, heat flux, pressure, and sweep gas in the reactor is controlled to the asphaltenes for further processing. The method according to [8] above, wherein a rich fraction is produced and solid asphaltenes in a dry state are produced as a final product.
[10] A processing apparatus for processing heavy hydrocarbons to produce a pipeline-ready or refinery-ready feedstock, the apparatus comprising:
a) a process fluid manufacturing component for mixing heavy hydrocarbons with other materials needed to prepare the process fluid;
b) means of transport for transferring the process fluid to the preheater;
c) the preheater capable of heating the process fluid to or near the desired operating temperature of the reactor;
d) transport means for transferring the heated process fluid to the reactor;
e) having heat exchange means for providing the desired heat flux to the process fluid and maintaining the process fluid in the reactor for a desired residence time at a substantially uniform desired temperature. Reactor;
f) means for supplying a sweep gas to the process fluid in the reactor;
g) Means for removing various produced materials from the reactor at the end of the residence time, where these materials comprise at least one of the following materials:
i. non-condensable vapor;
ii. light liquid hydrocarbons;
iii. Fraction rich in asphaltenes affected by heat;
h) means for separating non-condensable vapors from light liquid hydrocarbons;
i) means of transport for transferring the thermally affected fraction rich in asphaltenes to a solvent extraction processor;
j) the solvent extraction processor having means for removing the extracted product from the thermally affected asphaltene rich fraction, wherein these products are listed below:
i. Relapsed oil;
ii. resin;
iii. Concentrated dry solid asphaltenes;
k) Means for collecting an appropriate amount of the relapsed oil, resin and the light liquid hydrocarbon and blending them together to provide the pipeline-ready or refinery-ready feed.
[11] The apparatus according to [10], wherein the reactor is a single thermal conversion reactor equipped with an overhead condenser.
[12] Operation using a uniform heat flux of about 2.21 × 10 ⁴ to about 3.79 × 10 ⁴ W / m ² (7,000 to 12,000 BTU / hour · ft ² ) introduced into the process fluid in the reactor The apparatus according to [11] above.
[13] The apparatus according to [11], which operates using a sweep gas introduced into the reactor.
[14] The apparatus according to [11], wherein the ratio of the sweep gas to the process fluid is about 0.57 to about 2.27 m ³ / about 0.16 m ³ (20 to 80 scf / bbl).
[15] The apparatus according to [11], wherein the sweep gas is at least one of nitrogen, water vapor hydrogen, or light hydrocarbons such as methane, ethane, or propane.
[16] The apparatus according to [11] above, further comprising a heater for heating the sweep gas before being introduced into the reactor.
[17] The apparatus according to [11], wherein the apparatus operates continuously for a residence time of the process fluid in the reactor for 40 to 180 minutes.
[18] The apparatus according to [11], wherein the process fluid in the reactor is given a substantially uniform temperature of about 357 ° C to about 413 ° C (675-775 ° F).
[19] The apparatus according to [11], including the process fluid in the reactor at or near atmospheric pressure.
[20] The apparatus according to [11], which operates at a pressure lower than about 0.35 MPaG (50 psig).
[21] The apparatus according to [10] above, wherein the high shear mixing is performed on the thermally affected asphaltene extracted from the reactor in the item (g).

Claims (18)

An optimized and integrated method for producing pipeline- or refinery-ready feeds and dry, thermally affected asphaltene solids from heavy, high asphaltene feed process fluids Wherein the method comprises the following steps:
(a) preheating the process fluid in a heater to a designed temperature;
(b) transferring the preheated process fluid to a reactor and optimally converting the asphaltenes in the process fluid in the reactor to form a first fraction comprising a thermally affected asphaltene rich fraction. Producing a stream and a second stream of steam;
(c) separating the second stream of steam into a third stream of non-condensable steam and a fourth stream of lighter liquid hydrocarbons;
(d) the asphaltene-rich fraction affected by the heat of the first stream is desaturated by a solvent extraction method to obtain a fifth stream consisting of heavy, de-histored oil (DAO) and Making a sixth stream of concentrated asphaltenes;
(e) blending the fifth stream of heavy DAO and the fourth stream of liquid hydrocarbons into the pipeline- or refinery-ready feed; and
(f) The sixth stream comprising the concentrated asphaltenes, in the inertial separation unit, in the dry state, the seventh stream comprising the solid asphaltenes and the eighth stream comprising the solvent for reuse in the process. The process of separating into streams. The process of claim 1 as a continuous process, wherein the reactor is a single thermal conversion reactor with an overhead condenser operating within the following parameters:
(a) a uniform heat flux in the range of about 2.21 × 10 ⁴ to about 3.79 × 10 ⁴ W / m ² (7,000 to 12,000 BTU / hr · ft ² ) introduced into the process fluid in the reactor;
(b) introducing a sweep gas of about 0.57 to about 2.27 m ³ / about 0.16 m ³ (20-80 scf / bbl) (gas / process fluid) into the reactor;
(c) residence time of the process fluid in the reactor for 40 to 180 minutes;
(d) a substantially uniform operating temperature in the reactor from about 357 ° C. to about 413 ° C. (675-775 ° F.); (e) <about 0.35 MPaG (<50 psig) in the reactor Operating pressure at normal pressure. The process of claim 1 as a continuous process, wherein the solvent escape history is performed by a shear mixer, a simple asphalt extractor and a low pressure DAO / solvent recovery stripper operating at the following parameters:
(a) a solvent in the range of C6-C7;
(b) solvent to oil mass ratio in the range of 2-4: 1;
(c) critical temperature of the solvent-asphalt extractor operating temperature ranging from about 22.2 ° C (-40 ° F) to about 72.2 ° C (130 ° F);
(d) Critical pressure of the solvent—asphalt extractor operating pressure ranging from about 0.28 MPaG (−40 psig) to about 1.65 MPaG (240 psig). The feedstock sent to the process has an API in the range of 0-12, the feedstock to be sent sent to the solvent devolatilization step has an API in the range of -8-0, and the inertial separation 2. The method of claim 1, wherein the resulting feedstock sent to the unit is a solid at a temperature greater than about 371 ° C (700 ° F). The method of claim 1, wherein the solvent is part of a diluent (range C ₅ -C ₈ ) used to transport the bitumen feedstock to the site. SDA preheater, and the first SDA unit and the second S DA units disposed in this order performs the solvent extraction process of step (d), the flow between the SDA preheater and the first SDA unit or the first, flow between said as one SDA unit second S DA unit performs a high shear mixing process, the process of claim 1. A processing apparatus for processing heavy hydrocarbons to produce pipeline-ready or refinery-ready feedstock, the apparatus comprising:
a) a process fluid manufacturing component for mixing heavy hydrocarbons with other materials needed to prepare the process fluid;
b) means of transport for transferring the process fluid to the preheater;
c) the preheater capable of heating the process fluid to or near the desired operating temperature of the reactor;
d) transport means for transferring the heated process fluid to the reactor;
e) having heat exchange means for providing the desired heat flux to the process fluid and maintaining the process fluid in the reactor for a desired residence time at a substantially uniform desired temperature. Reactor;
f) means for supplying a sweep gas to the process fluid in the reactor;
g) A variety of the material generated, at the end of the residence time, means for extracting from said reactor, wherein these substances include substances least hereinafter:
i. non-condensable vapor;
ii. light liquid hydrocarbons;
iii. Fraction rich in asphaltenes affected by heat;
h) means for separating non-condensable vapors from light liquid hydrocarbons;
i) means of transport for transferring the thermally affected fraction rich in asphaltenes to a solvent extraction processor;
j) the solvent extraction processor having means for removing the extracted product from the thermally affected asphaltene rich fraction, wherein these products are listed below:
i. Relapsed oil;
ii. resin;
iii. Solid asphaltene deposits;
k) Means for collecting appropriate amounts of the relapsed oil, resin and the light liquid hydrocarbon and blending them together to provide the pipeline-ready or refinery-ready feed;
l) An inertial separation unit for removing a solvent from a slurry containing solid asphaltenes and a solvent to obtain dry solid asphaltenes. 8. The apparatus of claim 7 , wherein the reactor is a single thermal conversion reactor with an overhead condenser. Operating with a uniform heat flux of about 2.21 × 10 ⁴ to about 3.79 × 10 ⁴ W / m ² (7,000 to 12,000 BTU / hr · ft ² ) introduced into the process fluid in the reactor. Item 9. The device according to Item 8 . 9. The apparatus of claim 8 , wherein the apparatus operates with a sweep gas introduced into the reactor. 9. The apparatus of claim 8 , wherein the ratio of the sweep gas to process fluid is about 0.57 to about 2.27 m < ³ > / about 0.16 m < ³ > (20 to 80 scf / bbl). The sweep gas, nitrogen, is at least one vapor hydrogen or light hydrocarbons, according to claim 8. 9. The apparatus of claim 8 , comprising a heater for heating the sweep gas prior to introduction into the reactor. 9. The apparatus of claim 8 , wherein the apparatus operates for a residence time of the process fluid in the reactor for 40 to 180 minutes continuously. The apparatus of claim 8 , wherein the process fluid in the reactor is provided with a substantially uniform temperature of about 357 ° C. to about 413 ° C. (675-775 ° F.). 9. The apparatus of claim 8 , comprising the process fluid in the reactor at or near atmospheric pressure. 9. The apparatus of claim 8 , wherein the apparatus operates at a pressure below about 0.35 MPaG (50 psig). 8. The apparatus of claim 7 , wherein high shear mixing is performed on the thermally affected asphaltenes removed from the reactor in paragraph (g).