WO2013044346A1 - Désasphaltage par solvant avec séparation cyclonique - Google Patents

Désasphaltage par solvant avec séparation cyclonique Download PDF

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Publication number
WO2013044346A1
WO2013044346A1 PCT/CA2011/001106 CA2011001106W WO2013044346A1 WO 2013044346 A1 WO2013044346 A1 WO 2013044346A1 CA 2011001106 W CA2011001106 W CA 2011001106W WO 2013044346 A1 WO2013044346 A1 WO 2013044346A1
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WO
WIPO (PCT)
Prior art keywords
reactor
stream
asphaltene
process fluid
refinery
Prior art date
Application number
PCT/CA2011/001106
Other languages
English (en)
Inventor
Gerald Bruce
Greg Diduch
Damien Hocking
Darius Remesat
Original Assignee
Meg Energy Corp.
Corscadden, Tom
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Meg Energy Corp., Corscadden, Tom filed Critical Meg Energy Corp.
Priority to SG11201401274PA priority Critical patent/SG11201401274PA/en
Priority to RU2014117517/05A priority patent/RU2014117517A/ru
Priority to KR1020187015333A priority patent/KR20180064553A/ko
Priority to EP11873058.9A priority patent/EP2760974B1/fr
Priority to PCT/CA2011/001106 priority patent/WO2013044346A1/fr
Priority to BR112014007815A priority patent/BR112014007815A2/pt
Priority to ES11873058T priority patent/ES2725551T3/es
Priority to MX2014003951A priority patent/MX355399B/es
Priority to CN201180075179.1A priority patent/CN104105780B/zh
Priority to AU2011378107A priority patent/AU2011378107A1/en
Priority to KR1020147010399A priority patent/KR20140092815A/ko
Publication of WO2013044346A1 publication Critical patent/WO2013044346A1/fr

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10C—WORKING-UP PITCH, ASPHALT, BITUMEN, TAR; PYROLIGNEOUS ACID
    • C10C3/00—Working-up pitch, asphalt, bitumen
    • C10C3/08—Working-up pitch, asphalt, bitumen by selective extraction
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
    • C10G21/003—Solvent de-asphalting
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10C—WORKING-UP PITCH, ASPHALT, BITUMEN, TAR; PYROLIGNEOUS ACID
    • C10C3/00—Working-up pitch, asphalt, bitumen
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10C—WORKING-UP PITCH, ASPHALT, BITUMEN, TAR; PYROLIGNEOUS ACID
    • C10C3/00—Working-up pitch, asphalt, bitumen
    • C10C3/10—Melting
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
    • C10G1/04—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal by extraction
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G55/00—Treatment of hydrocarbon oils, in the absence of hydrogen, by at least one refining process and at least one cracking process
    • C10G55/02—Treatment of hydrocarbon oils, in the absence of hydrogen, by at least one refining process and at least one cracking process plural serial stages only
    • C10G55/04—Treatment of hydrocarbon oils, in the absence of hydrogen, by at least one refining process and at least one cracking process plural serial stages only including at least one thermal cracking step
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G9/00—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/201—Impurities
    • C10G2300/205—Metal content
    • C10G2300/206—Asphaltenes
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/30—Physical properties of feedstocks or products
    • C10G2300/308—Gravity, density, e.g. API

Definitions

  • the present invention relates to a method of improving a heavy hydrocarbon, such as bitumen, to a lighter more fluid product and, more specifically, to a final hydrocarbon product that is refinery-ready and meets pipeline transport criteria without the addition of diluent.
  • a solid asphaltene by-product is created for easy handling and further processing.
  • the invention is targeted to enhance Canadian bitumen, but has general application in improving any heavy hydrocarbon.
  • sweet crude resources require less capital input and have a much lower cost of processing than heavy sour crudes.
  • the global availability of light, sweet crude to supply to refineries for the production of transportation fuels is on the decline making the processing of heavy sour crude an increasingly important option to meet the world's demand for hydrocarbon-based fuels.
  • Heavy oil upgraders basically achieve this by high intensity conversion processes which either release up to 20% by weight of the feedstock as a coke byproduct and another 5% as off-gas product, or require hydro-processing such as hydrocracking and hydro-treating to maximize the conversion of the heavy components in the feedstock to lighter, lower sulfur liquid products and gas.
  • Visbreaking or viscosity breaking a form of thermal cracking
  • a well known petroleum refining process in which heavy and/or reduced crudes are pyrolyzed, or cracked, under comparatively mild conditions to provide products that have lower viscosities and pour points, thus reducing required amounts of less-viscous and increasingly costly to obtain blending hydrocarbons known as diluent to improve fluidity of the crude, and make the crude meet minimum transport pipeline specifications (minimum API gravity of 19).
  • Coil-only visbreakers operate at about 900°F at the heater outlet with a residence time of about 1 minute. Gas oil is recycled to quench the reaction.
  • a vessel is used at the outlet of a furnace to provide additional residence time for cracking of the crude. The crude sits and continues to crack/react as the temperature slowly reduces.
  • the coil-and-soak visbreaker runs at heater outlet temperatures of 800°F. The soaker drum temperature reduces down to 700°F at the outlet with aggregate residence times of over 1 hour.
  • U.S. Pat. No. 4,454,023 a process for the treatment of heavy viscous hydrocarbon oil is disclosed, the process comprising the steps of: visbreaking the oil; fractionating the visbroken oil; solvent deasphalting the non-distilled portion of the visbroken oil in a two-stage deasphalting process to produce separate asphaltene, resin, and deasphalted oil fractions; mixing the deasphalted oil ("DAO") with the visbroken distillates; and recycling and combining resins from the deasphalting step with the feedstock initially delivered to the visbreaker.
  • DAO deasphalted oil
  • ⁇ 23 patent provides a means for upgrading lighter hydrocarbons (API gravity> 15) than Canadian Bitumen but is burdened by the misapplication of the thermal cracking technology that will over-crack and coke the hydrocarbon stream, and by the complexity and cost of a two-stage solvent deasphalting system to separate the resin fraction from the deasphalted oil. In addition, the need to recycle part of the resin stream increases the operating costs and complexity of operation.
  • a solvent deasphalting unit is installed upstream of a visbreaking unit to remove the asphaltenes from the visbreaking operation.
  • the visbreaking unit can now operate at higher temperatures to convert the heavier molecules to lighter hydrocarbon molecules without fouling, since the asphaltenes are removed from the product stream entirely.
  • the yield of the bitumen is greatly reduced (by 10-15%) since the early removal of the asphaltenes in the process prevents thermal conversion of this portion of the crude into a refinable product.
  • U.S. Pat. 4,428,824, U.S. Pat No 6,274,032 disclosed a process for treating a hydrocarbon feed source comprising a fractionator to separate the primary crude components, followed by a Solvent Deasphalting (SDA) unit to work on the heavier crude asphaltene rich component, and a mild thermal cracker for the non-asphaltene stream.
  • SDA Solvent Deasphalting
  • the asphaltene rich stream is processed in a gasification unit to generate syngas for hydrogen requirements.
  • Placing an SDA unit upstream of a thermal cracker reduces the overall yield of the bitumen as refinery feed, since the asphaltene portion of the crude, comprising up to 15% of Canadian bitumen, is removed from consideration for inclusion in some format as crude.
  • U.S. Pat. No. 5,601,697 a process is disclosed for the treatment of topped crude oil, the process comprising the steps of vacuum distilling the topped crude oil, deasphalting the bottoms product from the distillation, catalytic cracking of the deasphalting oil, mixing distillable catalytic cracking fractions (atmospheric equivalent boiling temperature of less than about 1 100 degrees F.) to produce products comprising transportation fuels, light gases, and slurry oil.
  • U.S. Pat. No. '697 is burdened by the complexity, cost, and technical viability of vacuum distilling a topped heavy crude to about 850°F and catalytic cracking the deasphalted oil to produce transportation fuels.
  • U.S. Patent application 2007/0125686 a process is disclosed where a heavy hydrocarbon stream is first separated into various fractions via distillation with the heavy component sent to a mild thermal cracker (visbreaker).
  • the remaining heavy liquid from the mild thermal cracker is solvent deasphalted in an open art SDA unit.
  • the asphaltenes separated from the SDA are used as feed to a gasifier.
  • the deasphalted oil is blended with the condensed mild thermal cracker vapour to form a blended product.
  • visbreaking faces the challenges of early coke generation.
  • the '686 patent application explains that the intent of this mild thermal cracker is to crack the non-asphaltene material exclusively, which is also not practical with Canadian bitumen.
  • additional energy is required in the distillation steps with most of the separated components being recombined for pipeline transport.
  • the concentrated asphaltene product from the SDA unit is mixed with solvent to transport as a liquid solution to a spray dryer.
  • the spray nozzle design and pressure drop dictates the size of liquid droplets that are formed.
  • the smaller the light hydrocarbon (solvent) droplet the faster it will flash completely to vapour.
  • the smaller the heavy hydrocarbon (asphaltene) particle the more surface area available for heat transfer to cool the heavy droplets down with the goal of producing a dry, non-sticky solid particle.
  • Additional cold gas is added to the bottom of the spray dryer to enhance cooling by additional convective heat transfer as well as increasing the droplet residence time by slowing its descent rate (via upward cooling gas flow) in order to reduce the size of the vessel (which tend to be extremely large). This arrangement is not required if the asphaltene particles that have settled out in the extractor are in a solid form in the solvent at the process operating temperature.
  • a stream to a gasifier is generated by mixing a hydrocarbon comprising one or more asphaltenes and one or more non-asphaltenes with a solvent, wherein a ratio of the solvent to the hydrocarbon is about 2: 1 to about 10: 1.
  • the asphaltene rich stream is transferred out of the SDA to a gasifier as a liquid stream.
  • the large quantities of solvent used in transport are consumed in the gasifier, downgraded in value to a fuel gas equivalent. Since the asphaltenes tend to be liquid, using a solvent to transport the material in the quantities stated is feasible. For a solid asphaltene, this method would require 10-20 times more solvent to transport and this quantity of expensive solvent would be consumed and its value reduced.
  • an improved process for producing a pipeline-ready crude and refinery feedstock from heavy crude oils is described, with said process consisting of: (1 ) optimal asphaltene conversion with minimum coke and offgas make , in a full bitumen stream, within a reactor to produce a thermally affected asphaltene-rich fraction, a minimum non-condensable vapour stream and an increased refinery-feed liquid stream; (2) deasphalting said thermally affected asphaltene-rich fraction into a refinery-feed liquid stream and a concentrated asphaltene stream; (3) Selectively hydrotreating specific hydrocarbon components as required for pipeline specification and, finally blending of all the liquid streams to produce a refinery feed; and (4) inertial separation of the concentrated solid asphaltene stream for conversion in a gasifier, power or asphalt plant.
  • bitumen is thermally treated to remove and convert/crack selected asphaltenes, which are then sufficiently separated in a more efficient solvent extraction process, reducing production of coke and isolating undesirable contaminants (like metals, MCR, and remaining asphaltenes).
  • the side chains are preferentially cleaved from the core asphaltene molecule to make desired vacuum gas oil to light hydrocarbon range components.
  • the remaining polyaromatic asphaltene cores remain solid at elevated temperatures and pressures above operating conditions and thus separate more readily than non-thermally affected asphaltenes resulting in improved separation processes, such as solvent deasphalting (50) and vapour-solid separation like inertial separation (1 10).
  • the heavier hydrocarbons in the bitumen are also mildly cracked to vacuum gas oil, gasoline and distillate boiling range components, 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 increased gas yield and a reduction in the overall crude yield of the original bitumen, and reduced reliability of the operation, increasing the operating cost of the facility.
  • the invention provides improved apparatus and method for producing a pipeline- ready and refinery-ready feedstock from heavy, high asphaltene crudes (for example, Canadian bitumen), and feedstocks, with utility for any virgin or previously processed hydrocarbon stream , the process and apparatus comprising a pre-heater for pre-heating a process fluid to a design temperature at or near the desirable operating temperature of a reactor; moving the process fluid into a reactor for conversion of the process fluid by controlled application of heat to the process fluid in the reactor so that the process fluid maintains a substantially homogenous temperature throughout the reactor to produce a stream of thermally affected asphaltene-rich fractions, and a stream of liquid hydrocarbon vapour with minimal non-condensable vapour.
  • a pre-heater for pre-heating a process fluid to a design temperature at or near the desirable operating temperature of a reactor
  • moving the process fluid into a reactor for conversion of the process fluid by controlled application of heat to the process fluid in the reactor so that the process fluid maintains a substantially homogenous temperature throughout
  • the stream of vapour is separated into two further streams: of non-condensable vapour, and of light liquid hydrocarbons.
  • the thermally affected asphaltene-rich fraction is deasphalted, using a solvent extraction process, into streams of deasphalted oil liquid, and concentrated asphaltene, respectively.
  • the deasphalted oil liquid and the light liquid hydrocarbons produced in the processes are blended to form a pipeline and refinery-ready feedstock.
  • the concentrated asphaltene is processed in a vapour-solid separation unit (e.g. inertial) to create a dry solid asphaltene by-product.
  • a sweep gas can be deployed in the reactor, and can be preheated to provide a heat flux source other than the reactor's heaters; similarly, the sweep gas assists in the removal of reactor vapour products.
  • Deasphalting can be achieved using an open-art solvent extraction process; since the initial process fluid has been separated so that only the heavy asphaltene-rich fractions require deasphalting, extraction processes using high solvent-to-oil ratios are feasible and economical. Improved solvent-extraction performance, using lower solvent to oil ratios and improved DAO yield can be achieved by further concentrating the asphaltene rich fraction before a final extraction step.
  • the process improves on open-art solvent deasphalting utilizing an additional solvent extraction column (rinse column) operating on the asphaltene-rich stream from the primary solvent extraction column to increase pipeline crude recovery and quality.
  • the SDA process may allow for some portion of the heavy asphaltene-rich hydrocarbon stream to be recycled and blended with the fresh feed to the reactor.
  • the resulting concentrated thermally-affected asphaltenes can be successfully processed in a vapour-solid separator such as a centrifugal collector, settling chamber or inertial separator to generate a dry, solid asphaltene by-product.
  • a vapour-solid separator such as a centrifugal collector, settling chamber or inertial separator to generate a dry, solid asphaltene by-product.
  • this invention provides an improved process for producing enhanced refinery feedstock and dry thermally-affected asphaltene solids from heavy hydrocarbon, said process comprising:
  • a sweep gas of between 20-80 scf/bbl (gas/process fluid) is introduced within the reactor;
  • the refinery feedstock comprises a blend of at least two of the produced streams to be pipeline ready, having an API of greater than 19 degrees gravity, and a viscosity less than 350 Cst at 8°C; one or more of the produced streams is treated to remove olefins.
  • the refinery feedstock comprises one or more of the produced streams, suitable for diverse refinery types by virtue of its proportion of vacuum residue.
  • the invention further provides a process where the integrated process is applied to an existing coker-based bitumen upgrader or refinery by accepting as feedstock the upgrader's or refinery's virgin or processed heavy hydrocarbon streams and providing light liquid hydrocarbon, and heavy deasphalted hydrocarbon process streams to the upgrader or refinery.
  • the integrated process is applied to an existing residue hydrocracking upgrader or refinery by accepting as feedstock the upgrader's or refinery's virgin or processed heavy hydrocarbon streams and providing light liquid hydrocarbon, and heavy deasphalted hydrocarbon process stream to the upgrader or refinery.
  • the integrated process is applied to a new bitumen Upgrader, new "sweet crude” refinery or an existing "sweet crude” refinery in lieu of a coking process by accepting as feedstock the upgrader's or refinery's virgin or processed heavy hydrocarbon streams and providing light liquid hydrocarbon, and heavy deasphalted hydrocarbon process streams to the upgrader or refinery.
  • Fig. 1 is a process diagram for forming a pipeline transportable hydrocarbon product from a heavy hydrocarbon feedstock
  • Fig. 2 is a process diagram pertaining specifically to a cracking process and liquid separation process
  • Fig. 3 is a process diagram for an exemplary solvent de-asphalting process.
  • Fig. 4 depicts an illustrative application of an integrated mild thermal cracking and improved solvent deasphalting process with an existing upgrader or refinery with a vacuum and/or coking unit according to one or more embodiments described.
  • Fig. 5 depicts a specific illustrative application from Fig. 4 of an integrated mild thermal cracking and improved solvent deasphalting process fed a vacuum bottoms stream from an existing upgrader or refinery with the various products from the integrated cracker/SDA sent to hydrocracking, resid [residual] hydrocracking and gasification units according to one or more embodiments described.
  • FIG. 1 is a process flow diagram depicting a process 10 for forming a hydrocarbon product 60 from a hydrocarbon feedstock 12, where the final hydrocarbon product 60 has sufficient characteristics to meet minimum pipeline transportation requirements (minimum API gravity of 19) and is a favourable refinery feedstock.
  • a process fluid 14 formed from a feedstock 12 of heavy hydrocarbon can be routed through a heater 20 to heat the process fluid 14 to a desired temperature level before it is routed to a reactor 30 where the process fluid 14 is controlled and maintained while it undergoes a mild controlled cracking process.
  • a light top fraction 32 can be routed from the reactor 30 to a gas liquid condensing separator process 40 and a heavy bottom fraction 34 can be routed to a high performance solvent extraction process 50.
  • Some of the outputs 44 from the gas liquid separation process 40 can be blended with some of the outputs 52, 54 of the high performance solvent extraction process 50 to result in a hydrocarbon product 60 that has sufficient physical characteristics to enable it to meet the required pipeline transport criteria without having to mix the final hydrocarbon product 60 with diluents from external sources, or requiring much reduced volumes of such diluent.
  • the feedstock 12 can be a heavy hydrocarbon (virgin or a previously processed stream), such as the heavy hydrocarbon obtained from a SAGD (steam assisted gravity drainage) process, for example Canadian Oil sands bitumen, or from any other suitable source of heavy hydrocarbon.
  • the feedstock 12 can have an API gravity in the range of O to 14.
  • a recycled portion 70 of the resin stream 54 output from the high performance solvent extraction process 50 can be blended with the incoming feedstock 12 to form the process fluid 14 that passes through process 10.
  • the resin stream may be added to the process fluid in instances in which further crude yield, and/or lighter crude, and/or asphaltene suppression is desired in order to meet treated product characteristic targets.
  • the resin recycle provides the operator with flexibility, through an adjustable flow parameter, to meet production specifications, and allows the plant to handle feedstock variations robustly.
  • the resin product 54 from the solvent extraction process 50 will typically have a relatively low API gravity.
  • the API gravity of the resin product 54 can have an API gravity between 0 and 10.
  • the resulting process fluid 14 can have a range of characteristics and particularly a range of API gravities.
  • the process fluid 14 (obtained entirely from the feedstock 12 or formed as a blend of feedstock 12 and resin product 54 from the solvent extraction process 50) can be routed to the heater 20 where the process fluid 14 can be heated to a desired temperature as it passes through the heater 20 before being routed to the reactor 30 to undergo mild thermal cracking.
  • Reactor 30 maintains a consistent fluid temperature through a uniform application of heat through-out the reactor to allow for mild thermal cracking to occur without coking being a concern or detrimental to the operation and/or performance of the reactor.
  • the heater 20 will heat the process fluid 14 to a temperature between 675-775°F before the process fluid 14 is introduced into the reactor 30.
  • the process fluid 14 (heated to between 675-775°F by the heater 20) undergoes a mild controlled cracking process.
  • Appropriately located heaters are provided in this reactor 30 to maintain the desired constant temperature generated in heater 20 and to apply uniform heat flux for the fluid 14.
  • the heaters provide indirect heat through any source readily available (electric, heat transfer fluid, radiant etc.). To ensure a uniform heat flux, mixing can be applied to the process fluid on a continuous or intermittent basis.
  • the reactor 30 can be operated in a manner, through optimizing primarily five inter-related process variables (Temperature, Pressure, Residence Time, Sweep Gas and Heat Flux), so as to reduce or even prevent coke from forming during the reaction, and minimizing gas production, while also providing optimal conversion of the asphaltene portion of the heavy hydrocarbon to refinery-ready feedstock components.
  • five inter-related process variables Temporization, Pressure, Residence Time, Sweep Gas and Heat Flux
  • the first and second variables involve applying a uniform heat flux between 7000-12000 BTU/hr sq.ft to the entire pool of process fluid in the reactor and maintaining a single operating temperature in the reactor between 675-775 °F. This may be achieved by the presence of appropriately sized and located heating devices in the reactor.
  • the number of heaters will be set by calculating the optimal dispersion of heat between any two heaters so as to have a uniform temperature throughout the pool and to avoid peak or spot temperatures significantly higher than the target temperature in the reactor.
  • the third reactor variable, residence time can be between 40-180 minutes in the reactor.
  • the fourth reactor variable, operating pressure can be maintained at near atmospheric pressure , in any case, to be less than 50 psig, with standard pressure control principles used for consistent performance.
  • the pressure range is controlled on the low end to prevent excessive, premature flashing of hydrocarbon, essentially bypassing the reactor, and limited on the high end to reduce secondary cracking and consequent increased gas yields.
  • the fifth reactor variable, hot sweep gas 36 in the same temperature range as the process fluid (675-775°F) 21 , is added to the process fluid 14 in the reactor 30 in the range of 20-80 scf/bbl.
  • the sweep gas 36 can be natural gas, hydrogen, produced/fuel gas from the process, steam, nitrogen or any other non-reactive, non-condensable gas that will not condense to a liquid.
  • Sweep gas in the dosage of 20-80 scf/bbl of feed is provided to remove the "lighter" hydrocarbon products (i.e. methane to ⁇ 750°F boiling point hydrocarbons) as soon as they are formed in the reactor 30 so that there is a minimum of secondary cracking which could increase gas make and potentially increase olefinic naphtha/distillate production.
  • "lighter" hydrocarbon products i.e. methane to ⁇ 750°F boiling point hydrocarbons
  • the sweep gas may also allow the reactor to operate closer to the desired operating pressure ( ⁇ 50 psig) and temperature.
  • the sweep gas 36 can also be used to provide additional heat and/or mixing to the process fluid 14 in the reactor 30.
  • the heat energy stream 22, for reactor 30 is uniformly (7000-12000 BTU/hrsq.ft) applied throughout the hydrocarbon residence time (40-180 minutes) in the reactor at the desired temperature (675-775 °F) and pressure (less than 50 psig) to minimize any local peak fluid temperatures which can initiate coking, and thereby allowing an increased thermal transfer of heat at a higher bulk temperature improving the conversion of hydrocarbons within reactor 30.
  • reaction kinetics favour optimum conversion of the asphaltenes that preferentially cleaves the outlying hydrocarbon chains creating desirable hydrocarbons (VGO and diesel range hydrocarbons) for the refiner without causing coking or increased gas production in the reactor.
  • Table 4 illustrates different configurations of asphaltenes for different types of crudes.
  • the proposed operating conditions of reactor 30 factor in the relative complexity and high degree of side chains on different crudes.
  • Table 4 Average molecular structures representing asphaltene molecules from different sources: A, asphaltenes from traditional heavy crudes; B, asphaltenes from Canadian bitumen (Sheremata et al, 2004).
  • Each variable may be changed independently, within the ranges suggested, based on the quality of feedstock provided or based on the quality of output desired. Since the 5 noted process variables are inter-related, a multi-variable process control scheme with a prescribed objective function (maximum yield to meet minimum product specifications) will be beneficial to ensure the process operates at an optimal point when any one of the variables is changed or the feed/product situation is altered.
  • a light overhead fraction 32 and a heavy bottoms fraction 34 can be removed from the reactor 30.
  • the light overhead fraction 32 of the output from the reactor 30 can contain non- condensable vapor products, light liquid hydrocarbon and heavier liquid hydrocarbon.
  • the vapor products can be vapors released from the process fluid 14, such as sour gas, while undergoing thermal cracking, as well as introduced and unconverted or unused sweep gas 36 that has passed through the reactor 30.
  • the overhead liquid fraction 32 will have a much higher API gravity than the bottom fraction 34.
  • the overhead liquid fraction 32 could typically have an API gravity of 26 or greater.
  • the overhead fraction 32 can be directed to a gas liquid separation unit 40, which can comprise a cooler 41 and separation drum 42, as an example, in which a portion of the overhead fraction 32 that is a condensable liquid product containing naphtha and heavier hydrocarbons can be separated from the gaseous components of the overhead fraction 32.
  • An off-gas line 43 containing undesirable gases such as sour gas can be provided at the separation drum 42 for those gases to be disposed of, recycled, or subjected to further treatment.
  • One or more liquid hydrocarbon streams can be produced from separation drum 42.
  • Stream 44 a heavier hydrocarbon than stream 46, can be sent to product blending, while stream 46 can be considered for further bulk hydro-treating prior to product blending.
  • the bottom fraction 34 can contain hydrocarbons, and modified asphaltenes. Although the characteristics of the bottom fraction 34 taken from the reactor 30 will vary depending on the process fluid 14 input into the reactor 30 and the reactor's operating parameters, in one aspect the bottom fraction 34 can have an API gravity ranging between -5 and 5.
  • Controllable process variables allow an operator to vary the performance of the reactor 30 to meet the needs of the final product based on changing characteristics of the incoming process fluid 14.
  • the controllability of the five inter-related variables, residence time, sweep gas, heat flux, temperature and pressure in the reactor 30 allow an operator to vary the performance of the reactor 30.
  • the five inter-related process variables can be optimized to avoid the production of coke and minimize the production of non-condensable vapors are produced in the reactor 30.
  • the operator can vary 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 yields and/or quality of the outputs 32, 34.
  • the operator can vary the sweep gas, temperature or pressure to achieve similar outcomes.
  • the process variables are inter-related and the minimization of coke and avoidance of excess gas make is challenging and is best determined by pilot operations.
  • the bottom fraction 34 from the reactor 30 can be fed to a high performance solvent extraction process 50 that can produce a thermally affected asphaltene stream 58, an extracted oil stream 52 and a resin stream 54.
  • the reactor 30 is operated in a manner that significantly limits and even prevents the formation of coke and reduces gas production while converting asphaltenes into more suitable components for downstream processing. Consequently, modified asphaltenes and other undesirable elements remain in the bottom fraction 34 that is removed from the reactor 30.
  • the bottom fraction 34 from the reactor 30 must be further treated using, for example, a high performance solvent extraction process 50.
  • the treatment of the bottom fraction 34 by solvent extraction process 50 allows the reactor 30 and the solvent extraction process 50 to be used in conjunction, to produce a suitable full range refinery feedstock crude.
  • the solvent extraction process 50 can comprise any suitable solvent extraction process. In one aspect, it can be a three stage super-critical solvent process that separates the asphaltenes from the resins in the bottom fraction 34.
  • the output of the solvent extraction process 50 can be an asphaltene stream 58, an extracted oil stream 52 and a resin stream 54.
  • the asphaltene stream 58 is typically undesirable and is removed from the process 10.
  • the extracted oil stream 52 can be of a relatively high quality, with an API gravity range of 9 to 1 .
  • the resin stream 54 is typically of a lower quality than the extracted oil stream 52, with an API gravity lower than the extracted oil stream 52. In one aspect, the resin stream 54 can have an API gravity in the range of 0 to 10 API gravity.
  • the extracted oil stream 52 and the resin stream 54 from the solvent extraction process 50 can be blended along with the liquid product stream 44 obtained from the liquid gas separator 40 to form a final hydrocarbon product 60 meeting the specifications of the pipeline and/ or the refinery, in one aspect, this final hydrocarbon product 60 would have an API gravity greater than 19. Typically, the final hydrocarbon product 60 would have a viscosity of 350 CentiStokes ("cSt") or less. Hydrotreating may be applied to the blended stream 60 in the event olefins need to be reduced to meet a specific pipeline and/or refinery specification.
  • the resin stream 54 is typically of a lesser 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 in order to form the final hydrocarbon product 60. As a result, this recycling portion of the resin stream will improve the quality of the final hydrocarbon product 60.
  • a high-performance solvent extraction process 50 may include a supplemental extraction process step, rinse column 50e, upstream of the asphaltene stream 58.
  • stream 61 can be sent to a secondary solvent extraction column.
  • additional solvent extraction is performed on the primary deasphalted oil, in the form of a resin extractor 5 Of, to provide a separate deasphalted heavy oil stream 66.
  • the additional solvent extraction step on the asphaltene-rich stream by rinse column 50e as shown in figure 3 uses standard liquid- liquid extraction with the same solvent used in the primary extractor.
  • the placement of this standard liquid-liquid column on the asphaltene-rich stream is unique and is beneficial, since the solvent to oil ratio can be economically increased within this column up to 20: 1 to increase the recovery of deasphalted oil, while the overall solvent use is reduced.
  • Solvent in stream 63 is added to the asphaltene-rich stream 61 to a very high solvent to oil ratio and is cooled further to enhance asphaltene precipitation and thus oil recovery within column 50e.
  • the deasphalted oil stream 64 is sent to the resin extractor 50f, to be further refined for product blending.
  • the bottoms stream, comprising concentrated thermally-affected asphaltenes and solvent, from the rinse column 50e becomes stream 58, and is sent for solvent recovery via distillation, stripping or flash drying.
  • a solvent-to-oil ratio of 3-4: 1 in the main extractor 50 a.b.c is only needed (240,000 BPD) to precipitate all of the thermally affected asphaltenes with minimum DAO entrainment.
  • the rinse column, 50e will have a feed of approximately 6,000 BPD of asphaltene-based components and 750-1000 BPD of crude.
  • a solvent to oil ratio of 15-20: 1 in the rinse column 50e would extract the remaining crude requiring up to 140,000 BPD of additional solvent.
  • the total solvent circulated is 380,000 BPD with the rinse column configuration shown as 50e, resulting in a 25% reduction in the amount of solvent circulated. The result is a significant reduction in energy consumption compared to a state of the art 3-stage extraction process.
  • This high performance solvent extraction scheme including column 50e, can be applied to an existing open-art solvent extraction scheme in operation to further increase crude yield and/or reduce operating costs by reducing total solvent circulation.
  • the new scheme can be used as an improvement to designs in heavy oil recovery that would normally use state-of-the-art solvent deasphalting.
  • the resulting asphaltene stream 58 can be processed in a 20% smaller asphaltene separation unit, 1 10.
  • the core portion of the remaining concentrated thermally-affected asphaltenes are solid even at elevated temperatures (above 700°F) with the side hydrocarbon chains removed, resulting in less volume for the asphaltene separation unit to handle.
  • the modified nature of the asphaltenes provides for the opportunity for more effective metals reclamation and better feedstock for a clean energy conversion technology (e.g. gasification, catalytic gasification, oxy-combustion for enhanced SAGD production).
  • the vapour-solid (e.g. inertial) separation unit, 1 10 separates the asphaltene solids from the solvent vapour and gas remaining in stream 58 using one or more forces, such as centrifugal, gravitational, and inertial. These forces move the asphaltene solid to an area where the forces exerted by the gas stream are minimal.
  • the separated solid asphaltene is moved by gravity into a hopper, where it is temporarily stored.
  • Unit 1 10 can be either a settling chamber, baffle chamber or centrifugal collector; a device that provides separation of solid and gas. Centrifugal collectors can either be single or multi- staged cyclones.
  • stream 58 can be injected with suitable low molecular weight gas (ex. Natural gas, or nitrogen) to provide pneumatic conveyance to the asphaltene solids, that otherwise would be provided by flashing solvent in the line.
  • suitable low molecular weight gas ex. Natural gas, or nitrogen
  • a pneumatic conveying system may transport solids up to approximately 50 mm size. The solid must be dry, with no more than 20% moisture and not sticky. The thermally- affected asphaltene solids meet the above criteria and thus the process benefits from the ability to use an inertial separation unit, 1 10.
  • a pneumatic conveying system In a pneumatic conveying system, most of the energy is used for the transport of the gas itself. The energy efficiency of a pneumatic conveying plant is therefore relatively low, but this is often outweighed by easy handling and, in well designed systems, dust free solutions. In general the length of a pneumatic system should not extend 300 m for each pneumatic unit. The products can be conveyed over long distances by connecting the systems in series. There are three basic designs of pneumatic transport systems that can be considered for transporting stream 58 to unit 1 10: ⁇ dilute phase conveying at a high gas speeds (e.g. 20 - 30 m/s) strand conveying at a limited gas speeds (e.g. 15 - 20 m/s)
  • Process 10 provides a crude feedstock that is pipeline compliant and is optimal for high conversion refiners.
  • Stream 60 has low metals ( ⁇ 20 wppm Ni+V), low asphaltenes ( ⁇ 0.3 wt%), a very low TAN number ( ⁇ 0.3 mg KOH/mg), no diluent, and is high in VGO range material (30-50% of crude).
  • the distillation quality of the crude produced in stream 60 will improve utilization of the highest profit-generating units while filling out the remaining units.
  • Table 5 shows the distillation curve of a representative feedstock (dilbit) and the produced refinery-ready feedstock which is a well-balanced crude when compared to other heavy refinery feedstock crudes such as WCS (Western Canada Select).
  • WCS has more heavy residue (950+°F material) requiring intense conversion and more light material than refiners can profitably refine to transportation fuels.
  • This may be expressed as a Nelson complexity index value of 4.0-4.5, significantly less than 9.0-10.0 for a coking and/or hydroprocessing scheme.
  • Another illustration of improved performance is the reduced energy requirement of 3.93 GJ/tonne feed when compared to a delayed coking process that requires an energy input of 4.70 GJ/tonne feed to operate. This is a 16.4% reduction in energy intensity compared to a delayed coking process.
  • process 10 When compared to a coking upgrading process and standard reactor and solvent extraction process, process 10 provides a significant improvement in yield by minimizing by-products (Coke and non-condensable hydrocarbons) as noted in Table 6.
  • Figure 4 shows an illustrative application of the integrated controlled thermal cracker and improved SDA to an existing upgrader.
  • the proposed integrated process, reactor 20, improved SDA 50, and asphaltene recovery, 1 10 can be placed upstream of a refiner' s/upgrader's coking unit.
  • the benefit to a refiner/upgrader is the ability to debottleneck the vacuum and coking unit and accept more heavy crude to the unit. More barrels processed on existing equipment equates to larger profits and economic returns.
  • the operating severity can be decreased, increasing the life of the coker by increasing the cycle time for the coker (from 12 to 24 hours), and producing less gas and coke and more product.
  • Stream 5 can be the bottoms streams from an atmospheric column, vacuum column, or a catalytic cracking unit, noted as unit 200 in Figure 4.
  • the integrated cracker and SDA process produces a DAO stream, 52, that can be further processed into transportation fuels, stream 401 , in a hydrocracking and hydrotreating complex, unit 400.
  • the integrated cracker and SDA process also can produce a resin quality stream, 54, that can be sent to a coking, FCC (fluidized catalytic cracking) and/or an asphalt plant for further processing into finished products.
  • FCC fluidized catalytic cracking
  • the solid asphaltenes generated as stream 1 1 1 can either be mixed with the coke generated in unit 300 or sent off-site for further processing (energy generation and/or sequestration).
  • Figure 5 shows a specific embodiment for a new design or revamp opportunity for a refinery and/or upgrader.
  • Unit 200 is a vacuum unit and the bottoms stream 5 is sent to the integrated cracker/SDA process, units 20,30,40,50,1 10.
  • the DAO stream, 52 is sent to the hydrocracking and hydrotreating unit, 400, along with stream 205 from the vacuum unit.
  • a resin stream, 54 is produced from unit 50, and sent to a residue hydrocracking unit, 500. With less asphaltenes, that are highly exothermic when reacted, sent to unit 500, the residue hydrocracker can run at higher conversions (+8-15%) producing more material as final transportation fuel product.
  • the solid asphaltene stream, 111, from unit 1 10 can be sent to the gasification unit for hydrogen generation.
  • the integrated process in Figure 3 can also can help sweet, low complexity (hydro-skimming) refiners take heavier, cheaper crudes which are more readily available, and thus reposition assets to capture more value.
  • the integrated process can be placed at the front of the refinery to provide the initially conditioning of the heavier crude.

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Abstract

La présente invention concerne un procédé d'amélioration d'hydrocarbures lourds, tels que du bitume, en un produit plus léger et plus fluide et, plus spécifiquement, en un produit hydrocarbure final qui est prêt pour la raffinerie et satisfait aux critères de transport en pipeline sans ajout de diluant. Un sous-produit d'asphaltène solide est généré pour manipulation et traitement ultérieur aisés. L'invention est ciblée pour améliorer du bitume canadien, mais a une application générale dans l'amélioration de n'importe quel hydrocarbure lourd. Le procédé comprend : (a) le préchauffage d'un fluide de traitement dans un dispositif de chauffage à une température spécifiée ; (b) le transfert du fluide de traitement préchauffé vers un réacteur, et la conversion optimale des asphaltènes dans le fluide de traitement dans le réacteur pour produire un flux de fraction(s) riche(s) en asphaltène thermiquement affectée(s), et un flux de vapeur non condensable et d'hydrocarbure(s) plus léger(s) ; (c) le désasphaltage du flux riche en asphaltène thermiquement affecté avec un procédé d'extraction par solvant en un flux de pétrole désasphalté lourd (DAO) et un deuxième flux contenant de l'asphaltène concentré ; (d) la séparation des matières solides d'asphaltène thermiquement affecté sec du deuxième flux dans une unité de séparation, la récupération du solvant de traitement ; (e) la production d'une matière première de raffinerie comprenant au moins un des flux produits.
PCT/CA2011/001106 2011-09-30 2011-09-30 Désasphaltage par solvant avec séparation cyclonique WO2013044346A1 (fr)

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SG11201401274PA SG11201401274PA (en) 2011-09-30 2011-09-30 Solvent de-asphalting with cyclonic separation
RU2014117517/05A RU2014117517A (ru) 2011-09-30 2011-09-30 Деасфальтизация растворителем с циклонной сепарацией
KR1020187015333A KR20180064553A (ko) 2011-09-30 2011-09-30 사이클론 분리를 이용한 용매 탈아스팔트화
EP11873058.9A EP2760974B1 (fr) 2011-09-30 2011-09-30 Désasphaltage par solvant avec séparation cyclonique
PCT/CA2011/001106 WO2013044346A1 (fr) 2011-09-30 2011-09-30 Désasphaltage par solvant avec séparation cyclonique
BR112014007815A BR112014007815A2 (pt) 2011-09-30 2011-09-30 separação ciclônica com solvente sem asfalteno
ES11873058T ES2725551T3 (es) 2011-09-30 2011-09-30 Desasfaltado con disolvente con separación ciclónica
MX2014003951A MX355399B (es) 2011-09-30 2011-09-30 Desasfaltado con solvente y separacion ciclonica.
CN201180075179.1A CN104105780B (zh) 2011-09-30 2011-09-30 具有旋风分离的溶剂脱沥青
AU2011378107A AU2011378107A1 (en) 2011-09-30 2011-09-30 Solvent de-asphalting with cyclonic separation
KR1020147010399A KR20140092815A (ko) 2011-09-30 2011-09-30 사이클론 분리를 이용한 용매 탈아스팔트화

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EP2804930A4 (fr) * 2012-01-17 2015-10-14 Meg Energy Corp Conversion peu complexe et à rendement élevé d'hydrocarbures lourds
US9481835B2 (en) 2010-03-02 2016-11-01 Meg Energy Corp. Optimal asphaltene conversion and removal for heavy hydrocarbons
US9834730B2 (en) 2014-01-23 2017-12-05 Ecolab Usa Inc. Use of emulsion polymers to flocculate solids in organic liquids
US9944864B2 (en) 2012-01-17 2018-04-17 Meg Energy Corp. Low complexity, high yield conversion of heavy hydrocarbons
US9976093B2 (en) 2013-02-25 2018-05-22 Meg Energy Corp. Separation of solid asphaltenes from heavy liquid hydrocarbons using novel apparatus and process (“IAS”)
US20200224103A1 (en) * 2019-01-15 2020-07-16 Suncor Energy Inc. Combined process to produce both a pipelineable crude and carbon fiber from heavy hydrocarbon
CN114317093A (zh) * 2021-12-23 2022-04-12 安徽国孚凤凰科技有限公司 一种废润滑油蒸馏馏分油的萃取装置及方法
US11731878B2 (en) 2021-07-14 2023-08-22 Suncor Energy Inc. Production of carbon fiber from asphaltenes

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CN114437771B (zh) * 2020-10-19 2024-02-27 中国石油化工股份有限公司 利用炼化油浆再生沥青活化剂的工艺方法
CN113278443A (zh) * 2021-06-02 2021-08-20 西安近代化学研究所 一种重质油的连续热裂解装置和方法
KR102622555B1 (ko) * 2021-08-26 2024-01-09 주식회사 동양환경 석유계 잔사유를 이용한 연속식 피치제조시스템
CN116123441A (zh) * 2023-02-16 2023-05-16 上海舜华新能源系统有限公司 一种可实现放散气体分类回收利用的加氢站系统及方法

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Cited By (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9481835B2 (en) 2010-03-02 2016-11-01 Meg Energy Corp. Optimal asphaltene conversion and removal for heavy hydrocarbons
US9890337B2 (en) 2010-03-02 2018-02-13 Meg Energy Corp. Optimal asphaltene conversion and removal for heavy hydrocarbons
EP2804930A4 (fr) * 2012-01-17 2015-10-14 Meg Energy Corp Conversion peu complexe et à rendement élevé d'hydrocarbures lourds
US9944864B2 (en) 2012-01-17 2018-04-17 Meg Energy Corp. Low complexity, high yield conversion of heavy hydrocarbons
US9976093B2 (en) 2013-02-25 2018-05-22 Meg Energy Corp. Separation of solid asphaltenes from heavy liquid hydrocarbons using novel apparatus and process (“IAS”)
US10280373B2 (en) 2013-02-25 2019-05-07 Meg Energy Corp. Separation of solid asphaltenes from heavy liquid hydrocarbons using novel apparatus and process (“IAS”)
US9834730B2 (en) 2014-01-23 2017-12-05 Ecolab Usa Inc. Use of emulsion polymers to flocculate solids in organic liquids
US20200224103A1 (en) * 2019-01-15 2020-07-16 Suncor Energy Inc. Combined process to produce both a pipelineable crude and carbon fiber from heavy hydrocarbon
US10920153B2 (en) * 2019-01-15 2021-02-16 Suncor Energy Inc. Combined process to produce both a pipelineable crude and carbon fiber from heavy hydrocarbon
US11453828B2 (en) * 2019-01-15 2022-09-27 Suncor Energy Inc. Combined process to produce both a pipelineable crude and carbon fiber from heavy hydrocarbon
US11731878B2 (en) 2021-07-14 2023-08-22 Suncor Energy Inc. Production of carbon fiber from asphaltenes
CN114317093A (zh) * 2021-12-23 2022-04-12 安徽国孚凤凰科技有限公司 一种废润滑油蒸馏馏分油的萃取装置及方法

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EP2760974A4 (fr) 2015-06-24
KR20140092815A (ko) 2014-07-24
CN104105780B (zh) 2017-05-17
BR112014007815A2 (pt) 2017-04-18
KR20180064553A (ko) 2018-06-14
SG11201401274PA (en) 2014-09-26
MX2014003951A (es) 2015-04-14
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