WO2012158247A1 - Procédé de traitement d'une alimentation bitumineuse par addition par étapes d'un liquide de pontage - Google Patents

Procédé de traitement d'une alimentation bitumineuse par addition par étapes d'un liquide de pontage Download PDF

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Publication number
WO2012158247A1
WO2012158247A1 PCT/US2012/028565 US2012028565W WO2012158247A1 WO 2012158247 A1 WO2012158247 A1 WO 2012158247A1 US 2012028565 W US2012028565 W US 2012028565W WO 2012158247 A1 WO2012158247 A1 WO 2012158247A1
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WIPO (PCT)
Prior art keywords
slurry
agglomerates
solvent
solids
bridging liquid
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PCT/US2012/028565
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English (en)
Inventor
Lu Han
Brian C. Speirs
Olusola B. Adeyinka
Thomas R. Palmer
Emilio Alvarez
Anjaneya S. Kovvali
David C. Rennard
Fritz Pierre, Jr.
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ExxonMobil Upstream Research Co
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ExxonMobil Upstream Research Co
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Priority to US14/112,203 priority Critical patent/US20140262964A1/en
Publication of WO2012158247A1 publication Critical patent/WO2012158247A1/fr
Anticipated expiration legal-status Critical
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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
    • 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
    • C10G1/045—Separation of insoluble materials
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/40—Characteristics of the process deviating from typical ways of processing
    • C10G2300/44—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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/80—Additives
    • C10G2300/805—Water

Definitions

  • the present disclosure relates generally to the field of hydrocarbon extraction from mineable deposits, such as bitumen from oil sands.
  • Solvent extraction processes for the recovery of the hydrocarbons have been proposed as an alternative to water extraction of oil sands.
  • the commercial application of a solvent extraction process has, for various reasons, eluded the oil sands industry.
  • a major challenge to the application of solvent extraction to oil sands is the tendency of fine particles within the oil sands to hamper the separation of solids from the hydrocarbon extract. Solids agglomeration is a technique that can be used to deal with this challenge.
  • Solids agglomeration is a size enlargement technique that can be applied within a liquid suspension to assist solid-liquid separation.
  • the process involves agglomerating fine solids, which are difficult to separate from a liquid suspension, by the addition of a second liquid.
  • the second liquid preferentially wets the solids but is immiscible with the suspension liquid.
  • the second liquid displaces the suspension liquid on the surface of the solids.
  • Solids agglomeration has been used in other applications to assist solid-liquid separation.
  • the process has been used in the coal industry to recover fine coal particles from the waste streams produced during wet cleaning treatments (see for example, U.S. Patent Nos. 3,856,668 (Shubert); 4, 153,419 (Clayfield); 4,209,301 (Nicol et al.); 4,415,445 (Hatem) and 4,726,810 (Ignasiak)).
  • Solids agglomeration has also been proposed for use in the solvent extraction of bitumen from oil sands. This application was coined Solvent Extraction Spherical Agglomeration (SESA). A more recent description of the SESA process can be found in Sparks et al., Fuel 1992 (71 ); pp 1349-1353.
  • SESA Previously described methodologies for SESA have not been commercially adopted.
  • the SESA process involves mixing oil sands with a hydrocarbon solvent, adding a bridging liquid to the oil sands slurry, agitating the mixture in a slow and controlled manner to nucleate particles, and continuing such agitation to permit these nucleated particles to form larger multi-particle spherical agglomerates for removal.
  • the bridging liquid is preferably water or an aqueous solution since the solids of oil sands are mostly hydrophilic and water is immiscible with hydrocarbon solvents.
  • the formed agglomerates are more easily separated from the organic solvent compared to un-agglomerated solids. This process permitted a significant decrease in water use, as compared with conventional water-based extraction processes.
  • the multi-phase mixture need only be agitated severely enough and for sufficient time to intimately contact the aqueous liquid with the fine solids.
  • the patent discloses that it is preferable that the type of agitation be a rolling or tumbling motion for at least the final stages of agglomeration. These types of motion should assist in forming compact and spherical agglomerates from which most of the hydrocarbons are excluded.
  • the formed agglomerates are referred to as macro-agglomerates because they result from the consolidation of both the fine particles (sized less than 44 ⁇ ) and the coarse particles (sized greater than 200 ⁇ ) found in the oil sands.
  • the additional solvent acts to wash the excess bitumen from the agglomerates.
  • the additional bridging liquid allows the agglomerates to grow by a layering mechanism and under the increasing compressive forces produced by the tapered rotating drum bed depth.
  • the compressive forces act to preferentially remove hydrocarbon liquid from the pores of the agglomerates such that, when optimal operating conditions are imposed, the pores of the agglomerates end up being filled with only the bridging liquid, and the solvent that remains on the surface of the agglomerates is easily recovered.
  • U.S. Patent No. 4,406,788 (Meadus et al.) describes a similar apparatus to that of U.S. Patent No. 3,984,287 (Meadus et al.), but where the extraction and agglomeration processes occurs within a single vessel. Within this vessel, the flow of solvent is counter-current to the flow of agglomerates which results in greater extraction efficiency.
  • sludge introduces other challenges such as the fact that the appropriate sludge may not be readily available at the mine site. Furthermore, the use of sludge as the bridging liquid leads to larger agglomerates that are more prone to entrapment of bitumen.
  • U.S. Patent No. 4,719,008 (Sparks et al.) describes a process to address the agglomeration challenge posed by varying ore grades by means of a micro-agglomeration procedure in which the fine particles of the oil sands are consolidated to produce agglomerates with a similar particle size distribution to the coarser grained particles of the oil sands.
  • a micro-agglomeration procedure the solid-liquid separation behavior of the agglomerated oil sands will be similar regardless of ore grade.
  • the micro-agglomeration process is described as occurring within a slowly rotating horizontal vessel.
  • the conditions of the vessel favor the formation of large agglomerates; however, a light milling action is used to continuously break down the agglomerates.
  • the micro-agglomerates are formed by obtaining an eventual equilibrium between cohesive and destructive forces. Since rapid agglomeration and large agglomerates can lead to bitumen recovery losses owing to entrapment of extracted bitumen within the agglomerated solids, the level of bridging liquid is kept as low as possible commensurate with achieving economically viable solid-liquid separation.
  • the desired amount of bridging liquid for the agglomeration process will depend on the ore quality and the chemistry of the fines. Because the ore quality and chemistry will change on a frequent basis as different mine shelves are progressed, the recipe of the agglomeration process may need to change accordingly in order to maintain the agglomeration output within an acceptable range.
  • the bridging liquid is either added directly to the dry oil sands or it is added to the oil sands slurry comprising the oil sands and the hydrocarbon solvent.
  • bitumen extraction and particle agglomeration occurs simultaneously.
  • the growth of agglomerates may hamper the dissolution of the bitumen into the solvent, it may lead to trapping of bitumen within the agglomerates, and it may result in an overall increase in the required residence time for bitumen extraction.
  • excessive agglomeration may occur in the locations of bridging liquid injection.
  • agglomerates will tend to be larger than the desired agglomerate size and result in an increase in the viscosity of the slurry.
  • a higher slurry viscosity may hamper the mixing needed to uniformly distribute the bridging liquid throughout the remaining areas of the slurry. Poor bridging liquid dispersion may result in a large agglomerate size distribution, which is not preferred.
  • An important step in the agglomeration process is the distribution of the bridging liquid throughout the liquid suspension. Poor distribution of the bridging liquid may result in regions within the slurry of too low and too high binging liquid concentrations. Regions of low bridging liquid concentrations may have no or poor agglomeration of fine solids, which may result in poor solid-liquid separation. Regions of high bridging liquid concentration may have excess agglomeration of solids, which may result in the trapping of bitumen or bitumen extract within the large agglomerates. In the process described in U.S. Patent No.
  • Coal mining processes often produce aqueous slurries comprising fine coal particles.
  • Solids agglomeration has been proposed as a method of recovering these fine coal particles, which may constitute up to 30 wt.% of the mined coal.
  • the hydrophobic coal particles are agglomerated within the aqueous slurry by adding an oil phase as the bridging liquid.
  • the coal particles become wetted with an oil layer and adhere to each other to form agglomerates.
  • the hydrophilic ash particles are not preferentially wetted by the oil phase and, as a result, remain un-agglomerated and suspended in the aqueous phase.
  • the agglomerated coal material, with reduced ash content, is readily separated from the aqueous slurry by mechanical methods such as screening.
  • U.S. Patent No. 4,153,419 (Clayfield et al.) describes a process for the agglomeration of coal fines within an aqueous slurry by staged addition of a bridging liquid to the aqueous slurry.
  • Each agglomeration stage comprises the addition of a bridging liquid to the slurry, agitation of the mixture, and removal of agglomerates from the aqueous slurry.
  • U.S. Patent No. 4,415,445 (Van Hattem et al.) describes a process for the agglomeration of coal fines within an aqueous slurry by the addition of a bridging liquid and the addition of seed pellets that are substantially larger than the coal fines.
  • the presence of seed pellets induces agglomerate growth to occur predominately by a layering mechanism rather than by a coalescence mechanism. Since the rate of agglomeration occurs much faster by layering compared to coalescence, the process described therein allows agglomerates to form very quickly so that, for a given residence time, a higher throughput of agglomerates can be obtained compared to the throughput obtainable in the absence of seed pellets.
  • the present disclosure relates to a method of processing a bituminous feed.
  • bituminous feed is contacted with an extraction liquor to form a slurry.
  • a bridging liquid is added to the slurry in at least two stages and solids within the slurry are agitated to form an agglomerated slurry comprising agglomerated solids and a low solids bitumen extract.
  • the bridging liquid is added to the slurry in regions having higher shear rates than a median shear rate within the slurry.
  • the agglomerates are then separated from the low solids bitumen extract.
  • Potential benefits may include the production of smaller and more uniform agglomerates. The former may lead to higher bitumen recoveries and the latter may improve the solid-liquid separation rate.
  • the present disclosure provides a method of processing a bituminous feed, the method comprising: a) contacting the bituminous feed with an extraction liquor to form a slurry, wherein the extraction liquor comprises a solvent; b) adding a bridging liquid to the slurry in at least two stages and agitating solids within the slurry to form an agglomerated slurry comprising agglomerates and a low solids bitumen extract; said bridging liquid being added to the slurry in regions having higher shear rates than a median shear rate within the slurry; and c) separating the agglomerates from the low solids bitumen extract.
  • Fig. 1 is a flow chart illustrating a disclosed embodiment.
  • FIG. 2 is a schematic illustrating a disclosed embodiment.
  • FIG. 3 is a schematic illustrating a disclosed embodiment.
  • Fig. 4 is a schematic illustrating a disclosed embodiment.
  • Fig. 5 is a schematic illustrating a disclosed embodiment.
  • Fig. 6 is a schematic illustrating a disclosed embodiment.
  • the present disclosure relates to a method of processing a bituminous feed using staged addition of a bridging liquid. This method may be combined with aspects of other solvent extraction processes, including but not limited to those described above in the background section, and those described in Canadian Patent Application Serial No. 2,724,806 ("Adeyinka et al.”), filed December 10, 2010 and entitled “Processes and Systems for Solvent Extraction of Bitumen from Oil Sands”.
  • a solvent is combined with a bituminous feed derived from oil sand to form an initial slurry. Separation of the initial slurry into a fine solids stream and coarse solids stream may be followed by agglomeration of solids from the fine solids stream to form an agglomerated slurry.
  • the agglomerated slurry can be separated into agglomerates and a low solids bitumen extract.
  • the coarse solids stream may be reintroduced and further extracted in the agglomerated slurry.
  • a low solids bitumen extract can be separated from the agglomerated slurry for further processing.
  • the mixing of a second solvent with the low solids bitumen extract to extract bitumen may take place, forming a solvent-bitumen low solids mixture, which can then be separated further into low grade and high grade bitumen extracts. Recovery of solvent from the low grade and/or high grade extracts is conducted, to produce bitumen products of commercial value. Staged Addition of Bridging liquid
  • the present disclosure relates to a method of processing a bituminous feed.
  • the bituminous feed is contacted with an extraction liquor to form a slurry (102).
  • a bridging liquid is added to the slurry in at least two stages and solids within the slurry are agitated to form an agglomerated slurry comprising agglomerated solids and a low solids bitumen extract (104).
  • the bridging liquid is added to the slurry in regions having higher shear rates than a median shear rate within the slurry.
  • the agglomerates are then separated from the low solids bitumen extract (106).
  • Potential benefits may include the production of smaller and more uniform agglomerates. The former may lead to higher bitumen recoveries and the latter may improve the solid-liquid separation rate.
  • bituminous feed refers to a stream derived from oil sands that requires downstream processing in order to realize valuable bitumen products or fractions.
  • the bituminous feed is one that comprises bitumen along with undesirable components.
  • Such a bituminous feed may be derived directly from oil sands, and may be, for example raw oil sands ore. Further, the bituminous feed may be a feed that has already realized some initial processing but nevertheless requires further processing. Also, recycled streams that comprise bitumen in combination with other components for removal as described herein can be included in the bituminous feed.
  • a bituminous feed need not be derived directly from oil sands, but may arise from other processes.
  • bituminous feed may be used as a waste product from other extraction processes which comprises bitumen that would otherwise not have been recovered.
  • bituminous feed may be also derived directly from oil shale oil, bearing diatomite or oil saturated sandstones.
  • agglomerate refers to conditions that produce a cluster, aggregate, collection or mass, such as nucleation, coalescence, layering, sticking, clumping, fusing and sintering, as examples.
  • FIG. 2 is a schematic of a disclosed embodiment with additional steps including downstream solvent recovery.
  • the extraction liquor (202) is mixed with a bituminous feed (204) from oil sands in a slurry system (206) to form a slurry (208).
  • the extraction liquor comprises a solvent and is used to extract bitumen from the bituminous feed.
  • the slurry is fed into an agglomerator (210). Extraction may begin when the extraction liquor (202) is contacted with the bituminous feed (204) and a portion of the extraction may occur in the agglomerator (210).
  • a bridging liquid (212) is added to the agglomerator (210) to assist agglomeration of the slurry.
  • the low solids bitumen extract (218) is sent to a solvent recovery unit (222) to recover solvent (224) leaving a bitumen product (226).
  • the agglomerates (220) are sent to a tailings solvent recovery unit (228) to recover solvent (230) leaving dry tailings (232).
  • the bituminous feed is dry oil sands, which is contacted with extraction liquor that free of bridging liquid in a slurry system to produce a pumpable slurry.
  • the slurry may be well mixed in order to dissolve the bitumen.
  • the bridging liquid is then added to the slurry in order to agglomerate the fine solids within the slurry.
  • the rate of agglomeration may be controlled by a balance among agitation, fines content of the slurry, and bridging liquid addition.
  • the bitumen is first extracted from the bituminous feed prior to agglomeration in order to prevent (or limit) the agglomeration process from hampering the dissolution of bitumen into the extraction liquor.
  • the formed agglomerates are sized on the order of 0.1 -
  • At least 80 wt.% of the formed agglomerates are 0.1 -1 .0 mm or 0.1 to 0.3mm in size.
  • Figure 3 illustrates an embodiment where the bridging liquid is added to an agglomeration vessel at multiple locations within the vessel.
  • the bituminous feed (302) is added to an agglomerator (304).
  • Bridging liquid (306) is added at multiple stages along the flow path of the slurry. For example, multiple bridging liquid inlet ports may be arranged sequentially along the agglomerator.
  • the agglomerated slurry (308) is also shown.
  • the slurry may be well agitated so that the bridging liquid comes into contact with the solids within the slurry in order to form agglomerates.
  • the residence time between each stage of bridging liquid addition is sufficient to allow agglomeration of some of the fine particles within the slurry.
  • the residence time between each stage of bridging liquid addition may be greater than 30 seconds.
  • the formed agglomerates may be removed from the slurry.
  • Exemplary methods for removing the agglomerates include gravity separation or screening within the agglomerator. Agglomerates that are larger than 1 mm are typically undesirable due to the increased chance of bitumen entrapment within the large agglomerates.
  • These large agglomerates that are removed from the agglomerator may be separately comminuted by various methods known in the art to obtain agglomerates of the preferred size. For example, the agglomerates may be comminuted within attrition scrubbers or rod mills.
  • the bridging liquid is added to the slurry at relatively high agitation or mixing energy regions in order to improve the dispersion of the bridging liquid within the slurry. Therefore, the bridging liquid may be added to the slurry in regions having higher shear rates than a median shear rate within the slurry.
  • An example of a region of high shear rate within an agglomerator is adjacent the propellers of a mixing vessel such as an attrition scrubber.
  • the propellers themselves may contain suitable injection ports designed for injecting bridging liquid, at high shear, into the slurry.
  • the bridging liquid may be added to the slurry within the pumps used to transport the slurry.
  • the staged addition of bridging liquid may be used to assist in more uniformly agglomerating solids.
  • the amount of bridging liquid added at each stage of bridging liquid addition may be selected to obtain the desired agglomerate size.
  • FIG 4 illustrates an embodiment where the bridging liquid is added to an agglomeration vessel "continuously".
  • the bituminous feed (402) is added to an agglomerator (404).
  • Bridging liquid (406) is added "continuously” along the flow path of the slurry.
  • continuous means that the bridging liquid is added at stages separated by residence times that are significantly shorter than the residence time needed for agglomerate formation. For examples, the residence times between each bridging liquid stage may be less than 15 seconds, or less than 5 seconds.
  • the agglomerated slurry (408) is also shown.
  • FIG. 5 illustrates an embodiment where the bridging liquid is added to multiple agglomerators.
  • the bituminous feed (502) is added to a first agglomerator (504a), to which bridging liquid (506a) is added.
  • the slurry (503a) exists the first agglomerator (504a) and enters the second agglomerator (504b), to which bridging liquid (506b) is added.
  • the slurry (503b) exists the second agglomerator (504b) and enters the third agglomerator (504c), to which bridging liquid (506c) is added.
  • the agglomerated slurry (508) is also shown.
  • FIG. 6 illustrates an embodiment where agglomerates are removed from the slurry after they form and before the injection of additional bridging liquid.
  • the bituminous feed (602) is added to a first agglomerator (604x), to which bridging liquid (606x) is added.
  • the slurry (610) exists the first agglomerator (604x) and enters a solid- liquid separator (612) (examples of which are described below) separating agglomerates (614) from the reduced-solids slurry (616).
  • the reduced-solids slurry (616) is fed into the second agglomerator (604y), to which bridging liquid (606y) is added.
  • the agglomerated slurry (608) is also shown. More than two agglomerators and more than one solid-liquid separator could be used.
  • Exemplary methods for removing the agglomerates include, but are not limited to, gravity separators such as thickeners or enhanced gravity separators such as hydrocyclones.
  • the agglomerates may be removed from the slurry in order to reduce their additional growth. It has been shown in previous studies that in order to maximize bitumen recovery, it is desirable to keep the agglomerates average particle size to as low a value as possible commensurate with achieving economically viable solid liquid separation. If the agglomerates were to remain within the slurry, after subsequent bridging liquid additions, un- agglomerated fine particles would preferentially attach to the agglomerates, thus increasing the chances of bitumen entrapment within the growing agglomerates.
  • a portion of the agglomerates that are removed from the agglomerators may be separately comminuted by various methods known in the art to obtain agglomerates of the preferred size.
  • the agglomerates may be comminuted within attrition scrubbers or rod mills.
  • the agglomeration processes herein described may be used for the formation of macro-agglomerates or micro-agglomerates from the solids of the bituminous feed.
  • Macro-agglomerates are agglomerates that are predominantly greater than 2 mm in diameter. These agglomerates comprise both the fine particles (less than 44 ⁇ ) and sand grains of the oil sands.
  • Micro-agglomerates are agglomerates that are predominately less than 1 mm in diameter and they principally comprise fine particles of the oil sands. It has been found that for the SESA process described above, the formation of micro-agglomerates are more suitable for maximizing bitumen recovery for a range of oil sands grades.
  • Agglomeration is assisted by some form of agitation.
  • the form of agitation may be mixing, shaking, rolling, or another known suitable method.
  • the agitation of the feed need only be severe enough and of sufficient duration to intimately contact the bridging liquid with the solids in the feed.
  • Exemplary rolling type vessels include rod mills and tumblers.
  • Exemplary mixing type vessels include mixing tanks, blenders, and attrition scrubbers. In the case of mixing type vessels, a sufficient amount of agitation is needed to keep the formed agglomerates in suspension.
  • the solids content of the feed is, in one embodiment, greater than 40 wt.% so that compaction forces assist agglomerate formation.
  • the extraction liquor comprises a solvent used to extract bitumen from the bituminous feed.
  • solvent used to extract bitumen from the bituminous feed.
  • solvent should be understood to mean either a single solvent, or a combination of solvents.
  • the extraction liquor comprises a hydrocarbon solvent capable of dissolving the bitumen.
  • the extraction liquor may be a solution of a hydrocarbon solvent(s) and bitumen, where the bitumen content of the extraction liquor may range between 10 to 50 wt%. It may be desirable to have dissolved bitumen within the extraction liquor in order to increase the volume of the extraction liquor without an increase in the required inventory of hydrocarbon solvent(s). In cases where non-aromatic hydrocarbon solvents are used, the dissolved bitumen within the extraction liquor also increases the solubility of the extraction liquor towards dissolving additional bitumen.
  • the extraction liquor may be mixed with the bituminous feed to form a slurry where most or all of the bitumen from the oil sands is dissolved into the extraction liquor.
  • the solids content of the slurry is in the range of 10 wt% to 75 wt%, or 50 to 65 wt%.
  • a slurry with a higher solids content may be more suitable for agglomeration in a rolling type vessels, where the compressive forces aid in the formation of compact agglomerates.
  • For turbulent flow type vessels, such as an attrition scrubber, a slurry with a lower solids content may be more suitable.
  • the solvent used in the process may include low boiling point solvents such as low boiling point cycloalkanes, or a mixture of such cycloalkanes, which substantially dissolve asphaltenes.
  • the solvent may comprise a paraffinic solvent in which the solvent to bitumen ratio is maintained at a level to avoid or limit precipitation of asphaltenes.
  • a low boiling point solvent when it is used, there is the extra advantage that solvent recovery through an evaporative process proceeds at lower temperatures, and requires a lower energy consumption.
  • a low boiling point solvent when it is selected, it may be one having a boiling point of less than 100 °C.
  • the solvent selected according to certain embodiments may comprise an organic solvent or a mixture of organic solvents.
  • the solvent may comprise a paraffinic solvent, an open chain aliphatic hydrocarbon, a cyclic aliphatic hydrocarbon, or a mixture thereof.
  • a paraffinic solvent may comprise an alkane, a natural gas condensate, a distillate from a fractionation unit (or diluent cut), or a combination of these containing more than 40% small chain paraffins of 5 to 10 carbon atoms. These embodiments would be considered primarily a small chain (or short chain) paraffin mixture.
  • the alkane may comprise a normal alkane, an iso-alkane, or a combination thereof.
  • the alkane may specifically comprise heptane, iso- heptane, hexane, iso-hexane, pentane, iso-pentane, or a combination thereof.
  • a cyclic aliphatic hydrocarbon be selected as the solvent, it may comprise a cycloalkane of 4 to 9 carbon atoms. A mixture of C 4 -C 9 cyclic and/or open chain aliphatic solvents would be appropriate.
  • Exemplary cycloalkanes include cyclohexane, cyclopentane, or a mixture thereof.
  • the solvent is selected as the distillate from a fractionation unit, it may for example be one having a final boiling point of less than 180 °C.
  • An exemplary upper limit of the final boiling point of the distillate may be less than 100 °C.
  • a mixture of C 4 -Ci 0 cyclic and/or open chain aliphatic solvents would also be appropriate.
  • it can be a mixture of C 4 -C 9 cyclic aliphatic hydrocarbons and paraffinic solvents where the percentage of the cyclic aliphatic hydrocarbon in the mixture is greater than 50%.
  • Extraction liquor may be recycled from a downstream step.
  • solvent recovered in a solvent recovery unit may be used to wash agglomerates, and the resulting stream may be used as extraction liquor.
  • the extraction liquor may comprise residual bitumen and residual solid fines.
  • the solvent may also include additives. These additives may or may not be considered a solvent per se. Possible additives may be components such as de-emulsifying agents or solids aggregating agents. Having an agglomerating agent additive present in the bridging liquid and dispersed in the first solvent may be helpful in the subsequent agglomeration step.
  • Exemplary agglomerating agent additives included cements, fly ash, gypsum, lime, brine, water softening wastes (e.g. magnesium oxide and calcium carbonate), solids conditioning and anti-erosion aids such as polyvinyl acetate emulsion, commercial fertilizer, humic substances (e.g. fulvic acid), polyacrylamide based flocculants and others.
  • Additives may also be added prior to gravity separation with the second solvent to enhance removal of suspended solids and prevent emulsification of the two solvents.
  • Exemplary additives include methanoic acid, ethylcellulose and polyoxyalkylate block polymers. Bridging Liquid
  • a bridging liquid is a liquid with affinity for the solids particles in the bituminous feed, and which is immiscible in the solvent.
  • Exemplary aqueous liquids may be recycled water from other aspects or steps of oil sands processing.
  • the aqueous liquid need not be pure water, and may indeed be water containing one or more salt, a waste product from conventional aqueous oil sand extraction processes which may include additives, aqueous solution with a range of pH, or any other acceptable aqueous solution capable of adhering to solid particles within an agglomerator in such a way that permits fines to adhere to each other.
  • An exemplary bridging liquid is water.
  • the total amount of bridging liquid added to the slurry may be such that a ratio of bridging liquid to solids within the agglomerated slurry is in the range of 0.02 to 0.25, or 0.05 and 0.1 1.
  • the amount of bridging liquid that makes up this ratio includes the bridging liquid added to the slurry and the connate water from the bituminous feed.
  • the amount of bridging liquid that is added at a stage may be the same for each stage, or may be different.
  • the bridging liquid may contain fine particles (sized less than 44 ⁇ ) suspended therein. These fine particles may serve as seed particles for the agglomeration process.
  • the bridging liquid has a solids content of less than 40 wt.%. In one embodiment, the agglomerated slurry has a solids content of 20 to 70 wt.%.
  • the composition of the bridging liquid may be the same or different depending on which stage along the along the slurry flow path the bridging liquid is added. Additionally, the amount of the bridging liquid that is added to the slurry at each stage of bridging liquid addition may be the same or different.
  • the bridging liquid added during a first stage may have a salinity that is at least 10% higher or lower than a salinity of a bridging liquid added during a second, subsequent stage.
  • the bridging liquid added during a first stage may have a suspended solids content that is at least 10 % higher or lower than a suspended solids content of a bridging liquid added during a second, subsequent stage.
  • bitumen recovery increased by as much as five percentage points when the bridging liquid was added into the process vessel at intermittent time intervals during the agglomeration process compared to the case where all the bridging liquid was added at the beginning of the agglomeration process.
  • the improved bitumen recovery performance demonstrated by the staged bridging liquid addition is also supported by observations made during batch testing of the solids agglomeration process within a mixing vessel. In these tests, a translucent organic fluid was used as the continuous phase with sand and clay as the solids, and water as the bridging liquid.
  • the process may be adjusted to render the ratio of the solvent to bitumen in the agglomerator at a level that avoids precipitation of asphaltenes during agglomeration.
  • Some amount of asphaltene precipitation is unavoidable, but by adjusting the amount of solvent flowing into the system, with respect to the expected amount of bitumen in the bituminous feed, when taken together with the amount of bitumen that may be entrained in the extraction liquor used, can permit the control of a ratio of solvent to bitumen in the agglomerator.
  • the solvent is assessed for an optimal ratio of solvent to bitumen during agglomeration, the precipitation of asphaltenes can be minimized or avoided beyond an unavoidable amount.
  • Another advantage of selecting an optimal solvent to bitumen ratio is that when the ratio of solvent to bitumen is too high, costs of the process may be increased due to increased solvent requirements.
  • An exemplary ratio of solvent to bitumen to be selected as a target ratio during agglomeration is less than 2:1.
  • a ratio of 1.5:1 or less, and a ratio of 1 :1 or less, for example, a ratio of 0.75:1 would also be considered acceptable target ratios for agglomeration.
  • ratios may be expressed herein using a colon between two values, such as "2:1 ", or may equally be expressed as a single number, such as "2", which carries the assumption that the denominator of the ratio is 1 and is expressed on a weight to weight basis.
  • the slurry system may optionally be a mix box, a pump, or a combination of these.
  • the bitumen entrained within the feed is given an opportunity to become extracted into the solvent phase prior to agglomeration within the agglomerator.
  • the agglomerated slurry may be separated into a low solids bitumen extract and agglomerates in a solid-liquid separator.
  • the solid-liquid separator may comprise any type of unit capable of separating solids from liquids, so as to remove agglomerates. Exemplary types of units include a gravity separator, a clarifier, a cyclone, a screen, a belt filter or a combination thereof.
  • the system may contain a solid-liquid separator but may alternatively contain more than one.
  • a solid-liquid separator When more than one solid-liquid separation step is employed at this stage of the process, it may be said that both steps are conducted within one solid-liquid separator, or if such steps are dissimilar, or not proximal to each other, it may be said that a primary solid-liquid separator is employed together with a secondary solid-liquid separator.
  • primary and secondary units are both employed, generally, the primary unit separates agglomerates, while the secondary unit involves washing agglomerates.
  • Non-limiting methods of solid-liquid separation of an agglomerated slurry are described in Canadian Patent Application Serial No. 2,724,806 (Adeyinka et al.), filed December 10, 2010.
  • a secondary stage of separation may be introduced for countercurrently washing the agglomerates separated from the agglomerated slurry.
  • the initial separation of agglomerates may be said to occur in a primary solid-liquid separator, while the secondary stage may occur within the primary unit, or may be conducted completely separately in a secondary solid-liquid separator.
  • countercurrently washing it is meant that a progressively cleaner solvent is used to wash bitumen from the agglomerates.
  • Solvent involved in the final wash of agglomerates may be re-used for one or more upstream washes of agglomerates, so that the more bitumen entrained on the agglomerates, the less clean will be the solvent used to wash agglomerates at that stage. The result being that the cleanest wash of agglomerates is conducted using the cleanest solvent.
  • a secondary solid-liquid separator for countercurrently washing agglomerates may be included in the system or may be included as a component of a system described herein.
  • the secondary solid-liquid separator may be separate or incorporated within the primary solid-liquid separator.
  • the secondary solid-liquid separator may optionally be a gravity separator, a cyclone, a screen or belt filter.
  • a secondary solvent recovery unit for recovering solvent arising from the solid-liquid separator can be included.
  • the secondary solvent recovery unit may be conventional fractionation tower or a distillation unit.
  • the secondary stage for countercurrently washing the agglomerates may comprise a gravity separator, a cyclone, a screen, a belt filter, or a combination thereof.
  • the solvent used for washing the agglomerates may be solvent recovered from the low solids bitumen extract, as described with reference to Figures 2 to 4.
  • a second solvent may alternatively or additionally be used as described in Canadian Patent Application Serial No. 2,724,806 (Adeyinka et al.) for additional bitumen extraction downstream of the agglomerator.
  • the process may involve removal and recovery of solvent used in the process.
  • an exemplary solvent:bitumen ratio in the agglomerator may be 2:1 or lower, it is acceptable to use recycled solvent containing bitumen to achieve this ratio.
  • the amount of make-up solvent required for the process may depend solely on solvent losses, as there is no requirement to store and/or not re-use solvent that have been used in a previous extraction step. When solvent is said to be "removed”, or “recovered”, this does not require removal or recovery of all solvent, as it is understood that some solvent will be retained with the bitumen even when the majority of the solvent is removed.
  • the system may contain a single solvent recovery unit for recovering the solvent(s) arising from the gravity separator.
  • the system may alternatively contain more than one solvent recovery unit.
  • Solvent may be recovered by conventional means.
  • typical solvent recovery units may comprise a fractionation tower or a distillation unit.
  • the solvent recovered in this fashion will not contain bitumen entrained therein.
  • This clean solvent is preferably used in the last wash stage of the agglomerate washing process in order that the cleanest wash of the agglomerates is conducted using the cleanest solvent.
  • the solvent recovered in the process may comprise entrained bitumen therein, and can thus be re-used as the extraction liquor for combining with the bituminous feed.
  • Other optional steps of the process may incorporate the solvent having bitumen entrained therein, for example in countercurrent washing of agglomerates, or for adjusting the solvent and bitumen content prior to agglomeration to achieve the selected ratio within the agglomerator that avoids precipitation of asphaltenes.
  • Extraction Step may be Separate from Agglomeration Step
  • Solvent extraction may be conducted separately from agglomeration in certain embodiments of the process.
  • certain embodiments described herein include contact of the extraction liquor with the bituminous feed prior to the agglomeration step. This has the effect of reducing residence time in the agglomerator, when compared to certain previously proposed processes which require extraction of bitumen and agglomeration to occur simultaneously.
  • the instant process is tantamount to agglomeration of pre-blended slurry in which extraction via bitumen dissolution is substantially or completely achieved separately.
  • Performing extraction upstream of the agglomerator permits the use of enhanced material handling schemes whereby flow/mixing systems such as pumps, mix boxes or other types of conditioning systems can be employed. Additionally, performing extraction upstream of the agglomerator prevents the agglomeration process from hampering the dissolution of bitumen into the extraction liquor.
  • the residence time in the agglomerator may be reduced.
  • One other reason for this reduction is that by adding components, such as water, some initial nucleation of particles that ultimately form larger agglomerates can occur prior to the agglomerator.
  • Solvent may be added to the agglomerated slurry for dilution of the slurry before discharge into the primary solid-liquid separator, which may be for example a deep cone settler. This dilution can be carried out in a staged manner to pre-condition the primary solid-liquid separator feed to promote higher solids settling rates and lower solids content in the solid-liquid separator's overflow.
  • the solvent with which the slurry is diluted may be derived from recycled liquids from the liquid-solid separation stage or from other sources within the process.
  • the solvent to bitumen ratio of the feed into the agglomerator is set to obtain from about 10 to about 90 wt% bitumen in the discharge, and a workable viscosity at a given temperature. In certain cases, these viscosities may not be optimal for the solid-liquid separation (or settling) step. In such an instance, a dilution solvent of equal or lower viscosity may be added to enhance the separation of the agglomerated solids in the clarifier, while improving the quality of the clarifier overflow by reducing viscosity to permit more solids to settle.
  • dilution of agglomerator discharge may involve adding the solvent, or a separate dilution solvent, which may, for example, comprise an alkane.
  • the high energy requirements of solids agglomeration process is a well known limitation.
  • Embodiments described herein are expected to reduce the total energy needed to form the agglomerates.
  • the reduction in energy is due to the lower power requirement needed for the agglomeration process.
  • the reduction in power is due to the staged addition of bridging liquid. Since the bridging liquid is added in stages, the viscosity of the oil sands does not increase as much as it would if all the bridging liquid was added at once.
  • a reduction in the power requirement means that that the torque requirements of motors used in certain types of agglomeration vessel can be reduced. In the case of rotating type vessels, the required amount of milling can be reduced. Furthermore, the wear of the internals of the vessels will be dramatically reduced due to a reduction in the required mixing intensity.
  • staged addition of bridging liquid helps balance the rate of agglomeration with the rate of mixing.
  • the agglomeration of the solids occur at a rate that is much more rapid than the rate of mixing of the slurry.
  • the agglomeration process itself tends to hamper mixing by increasing the effective viscosity of the slurry.
  • the staged addition of the bridging liquid may modulate the rate of agglomeration at any particular location in the vessel.
  • the mixing of the slurry can match the agglomeration process to ensure that the slurry remains relatively homogeneous.
  • bridging liquid in high mixing energy regions of the slurry assist bridging liquid dispersion throughout the slurry. Additionally, removing the agglomerates from the slurry after each stage of bridging liquid addition reduces the viscosity of the slurry and prevents (or limits) excessive growth of the formed agglomerates.
  • Another potential advantage of certain embodiments is the shifting of the growth of agglomerates to a layering mechanism rather than a coalescence mechanism.
  • the layering mechanism refers to agglomerate growth where the individual fine particles stick on the surface of already formed agglomerates.
  • the coalescence mechanism refers agglomerate growth where two or more agglomerates stick together.
  • the layering mechanism should result in more compact agglomerates with less bitumen extract entrapped therein.
  • these agglomerates act as seed particles and shift the agglomeration process to more of a layering mechanism than a coalescence mechanism, which may dominate the agglomerate growth mechanism if all the bridging liquid was introduced in a single stage.
  • a Parr reactor (series 5100) (Parr Instrument Company, Moline, IL, USA) was used as the extractor and agglomerator.
  • the reactor vessel was made of glass that permits direct observation of the mixing process.
  • a turbine type impeller powered by an explosion proof motor of 0.25 hp was used.
  • the mixing and agglomeration speed of the impeller were set to 1500 rpm. This rotation speed allowed the slurry to remain fluidized at all conditions of the experiments.
  • the agglomeration experiments were conducted at room temperature (22 °C).
  • Soxhlet extractor combined with Dean-Stark azeotropic distillation, to determine the material contents of the agglomerated slurry.
  • Toluene was used as the extraction solvent.
  • the oil sand solids were dried overnight in an oven (100 °C) and then weighed to determine the solids content of the agglomerated slurry.
  • the water content was determined by measuring the volume of the collected water within the side arm of the Dean-Stark apparatus.
  • the bitumen content of the agglomerated slurry was determined by evaporating the toluene and residual cyclohexane from an aliquot of the hydrocarbon extract from the Soxhlet extractor.
  • the initial liquid drainage rate was calculated by measuring the time needed to drain 50 ml_ of bitumen extract above the bed of agglomerated solids.
  • the drainage rate of the agglomerates formed by using staged addition of the bridging liquid was approximately 3 times greater than that of agglomerates formed when all the bridging liquid is added in one stage (compare Experiment 3 to Experiment 1 ).
  • the drainage rate of the single stage agglomeration process can be increased by extending the agglomeration time (see Experiment 2) in order to form larger agglomerates.
  • the larger agglomerates results in a reduction in the bitumen recovery.
  • the staged addition of bridging liquid resulted in an increase in drainage rate without a significant reduction in bitumen recovery.

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

La présente invention concerne un procédé de traitement d'une alimentation bitumineuse. L'alimentation bitumineuse est mise en contact avec une liqueur d'extraction pour former une suspension. Un liquide de pontage est ajouté à la suspension en au moins deux étapes et les matières solides dans la suspension sont agitées pour former une suspension agglomérée comprenant des matières solides agglomérées et un extrait de bitume à faible teneur en matières solides. Les agglomérats sont ensuite séparés de l'extrait de bitume à faible teneur en matières solides. Les bénéfices potentiels peuvent inclure la production d'agglomérats plus petits et plus uniformes. Les premiers peuvent conduire à des récupérations de bitume plus élevées et les derniers peuvent améliorer le taux de séparation solide-liquide. Le liquide de pontage peut être ajouté dans une aire de taux de cisaillement relativement élevés. Entre les étapes d'addition du liquide de pontage, les agglomérats peuvent être éliminés.
PCT/US2012/028565 2011-05-18 2012-03-09 Procédé de traitement d'une alimentation bitumineuse par addition par étapes d'un liquide de pontage Ceased WO2012158247A1 (fr)

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CA2740468A CA2740468C (fr) 2011-05-18 2011-05-18 Methode de traitement d'une charge bitumineuse par l'ajout progressif d'un liquide portant
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US10703982B2 (en) 2017-11-21 2020-07-07 Syncrude Canada Ltd. In Trust For The Owners Of The Syncrude Project As Such Owners Exist Now And In The Future Process for solvent extraction of oil sand bitumen
CA3016908A1 (fr) 2018-09-07 2020-03-07 Suncor Energy Inc. Extraction non aqueuse du bitume des sables bitumineux
CA3051955A1 (fr) 2019-08-14 2021-02-14 Suncor Energy Inc. Extraction et separation non aqueuses de bitume a partir de minerai de sables bitumineux a l'aide d'un solvant paraffinique et de bitume desasphaltee
CA3169681C (fr) 2021-08-18 2025-12-23 Syncrude Canada Ltd. In Trust For The Owners Of The Syncrude Project As Such Owners Exist Now And In The Future Floculation/agglomeration de solides dans l'extraction de solvant du bitume de sable bitumineux

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US3984287A (en) * 1974-08-29 1976-10-05 Canadian Patents And Development Limited Apparatus for separating organic material from particulate tar sands and coal and agglomeration of the particulate residue
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US3542666A (en) * 1968-03-20 1970-11-24 Shell Oil Co Adjustment of ph in the filtration of tar sand solvent-water systems
US3984287A (en) * 1974-08-29 1976-10-05 Canadian Patents And Development Limited Apparatus for separating organic material from particulate tar sands and coal and agglomeration of the particulate residue
US4424112A (en) * 1982-05-28 1984-01-03 Solv-Ex Corporation Method and apparatus for solvent extraction
US4544477A (en) * 1983-10-12 1985-10-01 Standard Oil Company Polar solvent extraction and dedusting process
US5143598A (en) * 1983-10-31 1992-09-01 Amoco Corporation Methods of tar sand bitumen recovery
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US4719008A (en) * 1985-06-28 1988-01-12 Canadian Patents And Development Ltd. Solvent extraction spherical agglomeration of oil sands
US20080169222A1 (en) * 2004-10-15 2008-07-17 Kevin Ophus Removel Of Hydrocarbons From Particulate Solids
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WO2011021092A2 (fr) * 2009-08-17 2011-02-24 Brack Capital Energy Technologies Limited Extraction de sables bitumineux

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