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WO2019100140A1 - Installation de traitement d'hydrocarbures sans vapeur (valorisation) à multiples utilisations intégrées de gaz non condensable pour le traitement d'hydrocarbures - Google Patents

Installation de traitement d'hydrocarbures sans vapeur (valorisation) à multiples utilisations intégrées de gaz non condensable pour le traitement d'hydrocarbures Download PDF

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Publication number
WO2019100140A1
WO2019100140A1 PCT/CA2017/051398 CA2017051398W WO2019100140A1 WO 2019100140 A1 WO2019100140 A1 WO 2019100140A1 CA 2017051398 W CA2017051398 W CA 2017051398W WO 2019100140 A1 WO2019100140 A1 WO 2019100140A1
Authority
WO
WIPO (PCT)
Prior art keywords
gas
hydrocarbon
condensable
stripper
steam
Prior art date
Legal status (The legal status 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 status listed.)
Ceased
Application number
PCT/CA2017/051398
Other languages
English (en)
Inventor
Tom Corscadden
Frank David Guffey
Greg Diduch
Jim Kearns
Darius Remesat
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Meg Energy Corp
Original Assignee
Meg Energy Corp
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 filed Critical Meg Energy Corp
Priority to PCT/CA2017/051398 priority Critical patent/WO2019100140A1/fr
Publication of WO2019100140A1 publication Critical patent/WO2019100140A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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Classifications

    • 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
    • C10G29/00—Refining of hydrocarbon oils, in the absence of hydrogen, with other chemicals
    • C10G29/02—Non-metals
    • 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
    • C10G31/00—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for
    • C10G31/06—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by heating, cooling, or pressure treatment
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P30/00—Technologies relating to oil refining and petrochemical industry

Definitions

  • the present invention relates to operating the process of a hydrocarbon processing facility such as a refinery, heavy oil upgrader or petrochemical production plant without steam. Still more particularly the present invention employs a non-condensable gas in an integrated fashion as an alternate to steam in order to provide some, all or more features ordinarily provided by steam in a hydrocarbon processing facility but at a greatly reduced capital cost, operating cost and environmental footprint.
  • Hydrocarbon processors such as refiners, heavy oil upgraders and petrochemical plants, have been challenged to make a profit while providing improved environmental performance.
  • steam has been engrained into the basic design of the hydrocarbon processing complex since the first refinery.
  • Steam provides multiple uses including the initial motivation for steam use at a crude oil refinery, motive force for power generation to power pumps in hydrocarbon processing facilities.
  • steam has been applied to provide indirect heat transfer to the hydrocarbon to capture waste heat, provide increased velocity for the process fluid, known as velocity steam, through specific piping to mitigate coke formation and to also act as a stripping medium for hydrocarbon separation. Stripping with steam reduces the heat required to promote flashing at a given temperature and pressure by reducing the partial pressure of hydrocarbon in flash zone essentially reducing the flashing pressure of the hydrocarbon.
  • US patent 3,637,485 involves a process where the reactor effluent from a hydroconversion process is passed directly to an effluent stripper, components, hydrogen and light hydrocarbons are stripped by passing a hydrogen-rich gas stream through the stripper in countercurrent flow to said effluent and the hydrogen and light hydrocarbons from the effluent stripper are then passed to a feed stripper to strip oxygen eluant from the hydrocarbon feed which is utilized in the hydroconversion process.
  • This patent incorporates the use of a non-condensable gas that contains components that are a necessary part of the hydroconversion process differing from the integration and use of the non-condensable gas in the present invention.
  • US patent 4,014,780 shares a process for deoiling and dewatering refinery sludges in which sludges, optionally mixed with a diluent oil such as recycle oil recovered in the process, are contacted in a heating zone with steam or superheated steam to effect separation of the sludges into dry, oil-free, free-flowing solids and an oil-water vapor phase which, on condensation, yields a mixture of oil and water.
  • Patent #780 provides an example of steam use for stripping with heavy oils.
  • US patent application 20020068768 involves the use of an inert gas on a hydrotreated liquid containing volatile hydrocarbons, hydrogen, and contaminants such as hydrogen sulfide.
  • An inert gas preferably nitrogen
  • This stripper gas is then added to fuel gas fed to a combustion turbine, where combustibles in the fuel gas and stripper gas are combusted.
  • the stripping is at a pressure sufficient to allow the stripper gas, now containing hydrocarbons and hydrogen, to be added to the combustion turbine fuel without additional compression. This process allows for efficient use of the stripped combustibles, and the nitrogen added to the fuel gas provides increased power generation from the combustion turbine and reduces NOx emissions.
  • FIG 1 is a simplified flow diagram showing a hydrocarbon facility’s basic process units in an embodiment of this invention, using non-condensable gas in lieu of steam as both a stripping medium and a combustion fuel to provide heat to the process.
  • Figure 2 is a simplified flow diagram showing a hydrocarbon facility with a separation scheme involving a stripping gas.
  • Figure 3 is a simplified flow diagram showing a hydrocarbon facility using non-condensable gas in lieu of steam as both a stripping medium and a combustion fuel to provide heat to the process.
  • Figure 4 is a simplified flow diagram showing a hydrocarbon facility using non-condensable gas in lieu of steam as one of at least a stripping medium, a combustion fuel to provide heat to the process and to generate power in a turbine for the process with heat integration levels with the process.
  • a process for a heavy hydrocarbon processing operation that uses a non-condensable gas at operating conditions as a stripper gas, with the following process steps: providing a hydrocarbon liquid to a hydrocarbon treatment and separation vessel which is a stripper at a low pressure and elevated temperature; contacting the hydrocarbon liquid with stripper gas, thereby transferring at least a portion of volatile hydrocarbons in the hydrocarbon liquid to the stripper gas; removing the combined stripper gas and volatile hydrocarbons from the stripper; separating the stripper gas and the volatized hydrocarbons removed from the hydrocarbon liquid by condensing the volatized hydrocarbons; and conveying and recycling the non-condensable recovered stripper gas for reuse as the stripper gas in step b) as required.
  • that process uses non-condensable gas to strip and as a fuel gas to generate heat and/or power with the following added steps: conveying the separated stripper gas and any remaining volatized hydrocarbons to a fuel gas header for distribution as fuel; and one or more of: combusting the fuel as gas in a fired heater to produce heat which is conveyed to the hydrocarbon liquid; and injecting the fuel as gas into a turbine to generate power and recycle waste heat from the turbine to the process fluid directly; and removal for use in another setting or process as a fuel.
  • An apparatus for a heavy hydrocarbon processing operation for use of a non-condensable gas at operating conditions as a stripper gas, that comprises a phase-change hydrocarbon separation vessel; fluid management equipment to introduce a stream of heavy hydrocarbon and another stream of a non-condensable gas to the phase-change hydrocarbon separation vessel and treatment equipment associated with the vessel to promote vaporization of desired volatile components of the heavy hydrocarbon within the vessel; fluid management equipment to provide for discharge and collection of vapor from a first location within the vessel, the vapor containing both non-condensable gas and a vaporized portion of the heavy hydrocarbon; and additional fluid management equipment for the discharge of the remaining non-volatized treated liquid from a second and different location within the separation vessel.
  • the apparatus can comprise fluid management equipment to convey the vapors collected from the vessel to further processing equipment to separate the non-condensable gas from the condensable volatized hydrocarbon vapor thus collected; further fluid management equipment can be provided to: convey the condensable hydrocarbon for other use or sale; convey the non-condensable gas back to the vessel for re-use as a stripping gas; or to convey a portion of the non-condensable gas with some or none of the condensable hydrocarbon to a fuel header for further distribution for use as a fuel for power generation, combustion for heating, or other use.
  • a non-condensable gas at operating conditions to sequentially strip and generate heat for a heavy hydrocarbon processing operation is integrated into the facility by providing a hydrocarbon liquid to a stripper at a low pressure and elevated temperature, contacting the hydrocarbon liquid with a stripper gas, thereby transferring at least a portion of the volatile hydrocarbons in the hydrocarbon liquid to the stripper gas; separating the stripper gas from the volatized hydrocarbons in the hydrocarbon liquid by condensing the volatized hydrocarbons; conveying said stripper gas and remaining volatized hydrocarbons to a fuel gas header for feed to fired heaters to heat the heavy hydrocarbon liquid or to generate power and heat; combusting said fuel gas in the fired heater to convey heat to the hydrocarbon liquid, or generating electricity and recovering the waste heat directly with the process fluid or recycling the non-condensable gas for reuse as a stripping medium or a combination of
  • FIG. 1 depicts a simple process flow diagram depicting a hydrocarbon separation unit 20 using a fired heater 10.
  • a hydrocarbon stream 5, containing crude oil as an example is heated in the fired heater 10 to a temperature above the vaporization (flashing) point for a portion of stream 5.
  • the heat is generated from combustion of stream 110 which comprises a non-condensable stream 100 and a recycle of the non- condensable gas stream 200 used as a stripping medium along with any non-condensable material from stream 5.
  • the gas in stream 200 is typically natural gas and can include non condensable gases generated in the process.
  • the transfer of heat is from both radiant and convection means configured in any state of the art fired heater such as box, cabin or cylindrical vertical.
  • the heater 10 can heat the crude up to any temperature within the full boiling range to vaporize some of the stream.
  • the heater can heat up the material to just over the boiling point of the heaviest gasoline molecule, nominally 395°F (202°C) to vaporize a portion (around 15 weight%) of the hydrocarbon stream.
  • the two phase liquid and vapour stream 15 is sent to a hydrocarbon separation unit 20 to separate the hydrocarbon stream into desired separate streams, typically a non-condensable vapour stream, 120, a light condensed liquid stream, 29, and a heavy separated liquid stream, 25.
  • the hydrocarbon separation unit 20 can comprise any means of separation that involves liquid- vapor phase differences in the stream to effect the separation. Some common liquid-phase separation means used are distillation, stripping, and a simple flash drum.
  • a flash drum, 22, with a partial overhead condenser 24, and receiving drum 26, are used to separate the 40 API crude stream noted above which is heated to 395°F (202°C).
  • a partial overhead condenser 24, and receiving drum 26 are used to separate the 40 API crude stream noted above which is heated to 395°F (202°C).
  • At near atmospheric pressure in the flash drum 22, with no stripping gas in stream 110 around 47 weight% of the material is vaporized as stream 23, leaving 53 weight % as a liquid in stream 25. All the vaporized material in 23 is subsequently condensed in 24 and sent as stream 27 to the receiving drum 26.
  • With no stripping gas there is typically no vapour material in stream 120 and all the material in 27 which is 47 weight % of stream 15 becomes stream 29 and leaves as a liquid.
  • a scenario in table 1 includes stripping gas temperatures from the non-steam options to be closer to ambient conditions.
  • stripping gas temperature With the adjustment for stripping gas temperature, natural gas as a stripping medium is still comparable to steam while nitrogen is less effective than steam or natural gas.
  • Steam temperature is important so as not to counter the effects of the heat transfer from the fired heater with steam typically superheated above the separation vessel temperature when used as a stripping medium so that the impact of the latent heat of condensation (vaporization) is not realized.
  • This requirement for elevated steam stripping temperature adds another cost consideration for steam use. That is to say, the added cost of overheating the steam past process energy requirements due to other reasons such as to prevent premature condensation in steam delivery systems to the various processes, may be avoided.
  • a non-condensable product stream 120 results since natural gas will not normally condense and is not desired to condense in this application.
  • Stream 120 includes the stripping natural gas along with a small portion of the lightest components of stream 15 due to the equilibrium between the liquid and vapour phases.
  • Stream 120 can be sent directly to appropriately designed burners to a fired heater 10 or any other combustion equipment enabling the dual use of the non-condensable gas.
  • FIG. 3 illustrates the application of applying the present invention, dual use of non-condensable gas removing the need for process steam throughout a hydrocarbon processing facility. Stripping gas as stream 110 is provided to all operations such as hydrocarbon separation, 20, hydrocarbon conversion and any combination of hydrocarbon conversion and separation, 40.
  • the product non-condensable vapour streams, 120 and 140 are combined into stream 160 where all or parts of this stream can be used as combustion material in the fired heaters 10 and 30 or can be recycled via a compression unit, 190, for re-use as a stripping medium again.
  • the non condensable gases generated in units 20 and 40 may be sufficient that the requirement for sustained non-condensable gas supply (stream 100) is not always needed.
  • Table 2 shares a comparison of the key parameters for steam and a non condensable gas, such as natural gas, in a hydrocarbon facility.
  • natural gas when used as both a stripping and heat transfer medium, natural gas provides similar to better performance than steam while not requiring the capital and operating expenditures for the steam generation and handling in a conventional hydrocarbon facility.
  • the complexity of the facility is reduced when natural gas is used since it can be sent directly to the fuel gas header. Both steam and nitrogen need to be separated from any non-condensable vapour generated in the process since these molecules cannot be used for direct combustion in any appreciable quantities.
  • the non-condensable gas stream 160 can also be partially or fully used to generate electricity in unit 50 to power rotating equipment (turbine, other engines) or other power generation means in a hydrocarbon processing facility such as a crude refinery, bitumen upgrader, or petrochemical facility.
  • Unit 50 can be a gas turbine with the basic operation similar to that of the steam power plant except that the working fluid is air instead of water. Fresh atmospheric air flows through a compressor that brings it to higher pressure. Energy is then added by the non condensable fuel into the air and igniting it so the combustion generates a high-temperature flow.
  • This high-temperature high-pressure gas enters a turbine, where it expands down to the exhaust pressure, producing a shaft work output in the process.
  • the turbine shaft work is used to drive the compressor and other devices such as an electric generator that may be coupled to the shaft.
  • the energy that is not used for shaft work comes out in the exhaust gases, so these have either a high temperature or a high velocity.
  • direct heat exchange with the process fluid using single/multi-stream heat recovery and exchange equipment 520 and 540 can be employed.
  • the facilities required to generate steam, separate the condensed steam and clean the water for re-use increase the environmental impact with increased CO2 created.
  • the amount of CO2 avoided is the quantity of natural gas not burned to generate steam and the electrical power to operate these processes. Nominally, 117 lbs CO2 /mmbtu (50 k g CO2/GJ) is generated for the combustion of natural gas to vaporize water to create steam for stripping. As an example for a 100,000 barrel per day (15,900 m3/day) heavy oil refinery that generates 75 lbs of steam per barrel of feed (214 kg steam/m3 of feed), removing the steam generation facility translates to l40kTonnes/yr of CO2 avoidance.

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

Un gaz non condensable est utilisé comme alternative à la vapeur dans des installations de traitement d'hydrocarbures éliminant tout besoin de vapeur, ce qui permet de réduire les émissions de gaz à effet de serre et d'améliorer la rentabilité grâce à des réductions de capital et de coût de fonctionnement. Le gaz non condensable contribue à au moins deux fonctions séquentiellement dans le traitement d'hydrocarbures lourds ; premièrement, à fournir le gaz non condensable en tant que milieu de réextraction pour dégager les hydrocarbures plus légers à partir de la charge d'alimentation d'hydrocarbures lourds et, deuxièmement, à diriger le même gaz non condensable et tout gaz non condensable dégagé dans des conditions de fonctionnement pour une utilisation en tant qu'au moins l'un(e) parmi la chaleur par la combustion ou le courant électrique par la génération d'électricité.
PCT/CA2017/051398 2017-11-22 2017-11-22 Installation de traitement d'hydrocarbures sans vapeur (valorisation) à multiples utilisations intégrées de gaz non condensable pour le traitement d'hydrocarbures Ceased WO2019100140A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
PCT/CA2017/051398 WO2019100140A1 (fr) 2017-11-22 2017-11-22 Installation de traitement d'hydrocarbures sans vapeur (valorisation) à multiples utilisations intégrées de gaz non condensable pour le traitement d'hydrocarbures

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PCT/CA2017/051398 WO2019100140A1 (fr) 2017-11-22 2017-11-22 Installation de traitement d'hydrocarbures sans vapeur (valorisation) à multiples utilisations intégrées de gaz non condensable pour le traitement d'hydrocarbures

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WO2019100140A1 true WO2019100140A1 (fr) 2019-05-31

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Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3637485A (en) * 1969-09-26 1972-01-25 Chevron Res Hydrocarbon feed stripping with gas stripped from the reactor effluent
US4822480A (en) * 1987-12-22 1989-04-18 Mobil Oil Corporation Hydrocarbon product stripping
US5141630A (en) * 1990-03-15 1992-08-25 Lyondell Petrochemical Company Separation process employing two stripping gases
US20020068768A1 (en) * 2000-10-12 2002-06-06 Wallace Paul S. Nitrogen stripping of hydrotreater condensate
US20080099372A1 (en) * 2006-10-30 2008-05-01 Subramanian Annamalai Deasphalting tar using stripping tower

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3637485A (en) * 1969-09-26 1972-01-25 Chevron Res Hydrocarbon feed stripping with gas stripped from the reactor effluent
US4822480A (en) * 1987-12-22 1989-04-18 Mobil Oil Corporation Hydrocarbon product stripping
US5141630A (en) * 1990-03-15 1992-08-25 Lyondell Petrochemical Company Separation process employing two stripping gases
US20020068768A1 (en) * 2000-10-12 2002-06-06 Wallace Paul S. Nitrogen stripping of hydrotreater condensate
US20080099372A1 (en) * 2006-10-30 2008-05-01 Subramanian Annamalai Deasphalting tar using stripping tower

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