[go: up one dir, main page]

WO2012159209A1 - Procédé d'intégration de chaleur et d'eau destiné à une exploitation de sables bitumeux comprenant une injection directe de vapeur à la surverse chaude de l'épaississeur - Google Patents

Procédé d'intégration de chaleur et d'eau destiné à une exploitation de sables bitumeux comprenant une injection directe de vapeur à la surverse chaude de l'épaississeur Download PDF

Info

Publication number
WO2012159209A1
WO2012159209A1 PCT/CA2012/050287 CA2012050287W WO2012159209A1 WO 2012159209 A1 WO2012159209 A1 WO 2012159209A1 CA 2012050287 W CA2012050287 W CA 2012050287W WO 2012159209 A1 WO2012159209 A1 WO 2012159209A1
Authority
WO
WIPO (PCT)
Prior art keywords
water
steam
heat
integration process
warm
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/CA2012/050287
Other languages
English (en)
Inventor
Blair James Penner
Shawn Van Der Merwe
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.)
Fort Hills Energy LP
Original Assignee
Fort Hills Energy LP
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 Fort Hills Energy LP filed Critical Fort Hills Energy LP
Priority to US14/115,713 priority Critical patent/US20140076785A1/en
Publication of WO2012159209A1 publication Critical patent/WO2012159209A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

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
    • C10G1/047—Hot water or cold water extraction processes
    • 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
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D21/00—Separation of suspended solid particles from liquids by sedimentation
    • B01D21/26—Separation of sediment aided by centrifugal force or centripetal force
    • B01D21/267—Separation of sediment aided by centrifugal force or centripetal force by using a cyclone
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B03—SEPARATION OF SOLID MATERIALS USING LIQUIDS OR USING PNEUMATIC TABLES OR JIGS; MAGNETIC OR ELECTROSTATIC SEPARATION OF SOLID MATERIALS FROM SOLID MATERIALS OR FLUIDS; SEPARATION BY HIGH-VOLTAGE ELECTRIC FIELDS
    • B03D—FLOTATION; DIFFERENTIAL SEDIMENTATION
    • B03D2203/00—Specified materials treated by the flotation agents; Specified applications
    • B03D2203/006—Oil well fluids, oil sands, bitumen

Definitions

  • the present invention generally relates to the field of oil sands processing and in particular relates to a heat and water integration process for reuse of hot thickener overflow water.
  • Oil sands processing requires hot water for a number of unit operations.
  • oil sands ore preparation and primary separation cells require hot water.
  • recycle process water contains a number of contaminants such as residual bitumen, suspended mineral solids and various salts. Due to the composition of recycle process water, heating in conventional indirect heating devices - such as shell and tube or plate heat exchangers - results in fouling of heat transfer surfaces.
  • One known mitigation measure to combat this fouling is to install exchanger areas to facilitate maintenance and cleaning of heat transfer areas.
  • Thickeners are used in oil sands extraction and froth treatment operations to increase the solids concentration of an input stream and produce overflow water.
  • Thickener overflow water has been considered for reuse in upstream extraction processes after being heated to desired temperatures.
  • the variable composition of thickener overflow leads to fouling of heat exchanger transfer areas.
  • Thickener water is viewed as having low quality heat making it unsuitable for many applications in oil sands processing.
  • Direct steam injection is also known for heating bitumen froth prior to froth treatment, as disclosed in Canadian patent No. 2,455,01 1 (Gaston et al.).
  • direct steam injection is not suitable for several heating applications since the steam/condensate are lost to the process fluid, thus requiring higher upstream make-up water and water treatment requirements to compensate for the lost steam/condensate.
  • This is particularly the case for steam generation systems that produce high quality steam, e.g. over 600 psia, for steam/power cogeneration applications.
  • the present invention responds to the above-mentioned need by providing a process for heat and water integration of an oil sands extraction and bitumen production operation.
  • the invention provides a heat and water integration process for an oil sands operation, comprising:
  • the unit of the oil sand operation is selected from (i) an oil sand ore preparation unit and (ii) a primary separation unit.
  • the primary separation unit receives an oil sand slurry and froth for separation and at least a portion of the steam heated thickener water is used as froth under-wash in the primary separation unit.
  • the oil sand ore preparation unit receives oil sand ore and at least a portion of the steam heated thickener water is used as hot slurrying medium in the oil sand ore preparation unit.
  • the process includes supplying ambient recycle water from a pond to the unit of the oil sands operation.
  • the process includes combining a portion of the ambient recycle water with a portion of the warm water overflow component to produce a warm process water stream and supplying the warm process water stream to an oil sand ore preparation unit.
  • the process includes heating a portion of the ambient recycle water in a heat exchanger to produce a heated recycle water and supplying the heated process water to an oil sand ore preparation unit.
  • the process includes heating a portion of the ambient recycle water in a heat exchanger to produce a heated recycle water and supplying the heated process water to a primary separation unit.
  • the primary separation unit receives an oil sand slurry and froth for separation and at least a portion of the steam heated thickener water and the heated recycle water are combined and used as froth under-wash in the primary separation unit.
  • the process includes providing steam from a central steam source; using a first portion of the steam in the direct steam injection; and using a second portion of the steam for heating the ambient recycle water in the heat exchanger.
  • the warm water overflow component has a temperature between about 20 S C and about 45 S C higher than the recycle pond water.
  • the direct steam injection heats the warm water overflow component from an initial temperature between about 20 S C and about 50 S C to a temperature of the steam heated thickener overflow between about 70 S C and about 90 S C.
  • the temperature of the steam heated thickener overflow is between about 75 S C and about 85 S C.
  • the direct steam injection has a steam input between about 20 to 90 kG/ 1 of oilsand.
  • the steam input is between about 150 tonnes/hr and about 300 tonnes/hr.
  • the direction steam injection comprises maintaining sufficient backpressure on the steam heated thickener water downstream of the direction steam injection so as to sub-cool the warm water overflow component.
  • the direction steam injection uses steam selected from the group consisting of excess steam, low quality steam, wet steam, low pressure steam and blow-down steam.
  • the direction steam injection uses steam having a pressure at least 45 psia.
  • the direction steam injection uses steam containing non- condensable gases.
  • the direction steam injection uses saturated steam. In another optional aspect, the direction steam injection uses steam generated by a low pressure boiler.
  • the direction steam injection uses steam generated from condensate blowdown.
  • the process includes providing a knock-out or steam trap system upstream of the direction steam injection.
  • the process is conducted at least in wintertime.
  • the invention also provides a system for implementing the process and its embodiments as described above and herein.
  • the system includes a thickener that produces a thickened tailings component and a warm water overflow component, a direct steam injection device for subjecting at least a portion of the warm water overflow component to direct steam injection to produce a steam heated thickener water; a unit of the oil sand operation for receiving at least part of the steam heated thickener water.
  • Fig 1 is a process flow diagram of a bitumen production operation with direct steam injection (DSI) for hot thickener water.
  • DSI direct steam injection
  • Fig 2 is a process flow diagram of a bitumen extraction operation with hot thickener water DSI heating and integration.
  • Fig 3 is a process flow diagram of a froth treatment operation with a thickener for the froth treatment tailings.
  • Fig 1 illustrates an embodiment of the process of the present invention.
  • a bitumen production operation 10 receives oil sand 12 and produces a bitumen product 14.
  • the bitumen production operation 10 also receives other process streams and produces output streams.
  • One output stream is a warm tailings stream 16, which contains mineral solids such as sand, silt and clay, residual bitumen and components thereof and water in varying proportions depending on the particular source and processing conditions that generated the tailings.
  • the warm tailings stream 16 is produced by a tailings solvent recovery unit (TSRU) for treating the solvent diluted tailings from a bitumen froth separation unit (FSU).
  • TSRU tailings solvent recovery unit
  • FSU bitumen froth separation unit
  • the TSRU recovers the solvent from the solvent diluted tailings and generates TSRU tailings.
  • the warm tailings stream 16 is derived from middlings and/or bottoms of a primary separation vessel (PSV). More regarding the source of the warm tailings stream 16 and related reutilization of water and heat will be discussed further herein-below.
  • PSV primary separation vessel
  • the warm tailings stream 16 is supplied to a thickener 18 for producing a thickener underflow component 20 and a warm water overflow component 22.
  • the thickener 18 may have a variety of constructions and structural or operational aspects to achieve the separation. In one operational aspect, the thickener is as generally described in Canadian patent application No. 2,454,942 (Hyndman et al.), though it may alternatively have various other constructions.
  • the thickener may produce only the thickener underflow component 20 and the warm water overflow component 22 or it may have other outlets for producing additional streams such as a recovered hydrocarbon stream (not illustrated).
  • the thickener underflow component 20 may then be provided to a tailings disposal equipment or piping 24 and eventually be fed to a tailings pond.
  • the warm water overflow component 22 is subjected to direct steam injection (DSI) 26 to produce steam heated process water 28.
  • DSI direct steam injection
  • the steam heated process water 28 can then be used in the bitumen production operation 10.
  • Fig 1 illustrates an embodiment wherein the DSI 26 is used to heat thickener overflow water 22 by direct steam injection and the steam heated process water 28 is used as hot process water within the bitumen production process area.
  • Fig 2 illustrates an embodiment wherein the DSI 26 is used to heat thickener overflow water 22 by direct steam injection and the steam heated process water 28 is used as hot process water in an ore preparation area and as froth wash water in a primary separation vessel (PSV).
  • PSV primary separation vessel
  • the oil sand 12 is mixed with hot process water 30 which may contain excess steam heated thickener overflow 28 to form oil sand slurry 32 that is conditioned, i.e. liberates the bitumen from the sand in a conditioning slurry pipeline.
  • hot process water 30 which may contain excess steam heated thickener overflow 28 to form oil sand slurry 32 that is conditioned, i.e. liberates the bitumen from the sand in a conditioning slurry pipeline.
  • flotation froth 34 from a downstream unit is injected into the conditioned oil sand slurry 32 upstream of the separation cell 35 (also referred to as a "primary separation vessel (PSV)" and "sep cell” herein).
  • PSV primary separation vessel
  • An amount of the steam heated process water 28 may be added to the sep cell as froth under-wash 36 to improve the froth quality by washing and heating the bitumen froth as it rises through a hot water layer.
  • the water temperature is higher than the feed slurry, preferably 10 S C higher and still preferably 20 S C higher.
  • the sep cell 35 produces a bitumen froth overflow 38 that is transferred to froth treatment 39. Note that the bitumen production module 10 of Fig 1 encompasses froth treatment in which steam is a utility.
  • the sep cell 35 also produces a middlings stream 40 and a bottoms stream 42.
  • the middlings stream 40 is subjected to middling flotation 44 to produce flotation tailings 48 and middling flotation froth 46 to make up part of the flotation froth 34.
  • the middling floatation 44 may be conventional or column floatation.
  • the sep cell bottoms tailings 42 are combined with the middling flotation tailings 48 and the combined stream 50 is fed to a tailings cyclones 52.
  • Cyclone overflow 54 is processed by final flotation 56 (either conventional or column) to recover the remaining portion 58 to make up the flotation froth 34.
  • the warm tailings stream 16 is at least partially produced as underflow from the final floatation unit 56 which treats derivative middlings and bottoms streams from the sep cell 35.
  • the warm tailings stream 16 is processed by one or more thickeners 18 for water and heat recovery.
  • the thickeners 18 may also recover water from other warm tailings streams including froth treatment tailings (also referred to as TSRU tailings).
  • TSRU tailings also referred to as TSRU tailings.
  • a portion of recovered thickener water 22 is DSI heated and used where possible to minimize heat and water requirements from cold recycle water and indirect steam heat exchangers.
  • the steam heated thickener water 28 is employed as warm process water in extraction for flushing and other process operations.
  • the thickened tailings 20 from the thickener 18 are combined with cyclone tailings 60 as overall extraction tailings 62 that are transferred to the tailing disposal area 24.
  • Tailing water 64 is collected in a tailings pond 66 where suspended minerals settle and the tailings water cools to ambient conditions for reuse in bitumen extraction as recycle water 68.
  • Recycle water 68 is returned to extraction for general use as extraction water 70 (generally cold for flush purposes) and heated by steam heat exchangers 72 for use as hot process water 30 in ore preparation and optionally as part of the froth underwash water 36.
  • the steam heat exchangers 72 use natural gas 74 or other fuel sources supplied to steam boilers 76.
  • a water treatment plant 78 treats water make-up 80, typically river water, to produce treated water 82, so as to maintain condensate inventory for steam production. Condensate 84 from the steam heat exchangers 72 is recycled to steam boilers 76 to produce steam 86.
  • the steam used for the DSI is selected from excess, low quality, wet, low pressure or blow-down steam.
  • low quality, wet or low pressure steam which are not suited to many oil sand processing applications may be advantageously used for heating the thickener overflow water to produce steam heated thickener water which has high quality heat for reuse in extraction or production processes.
  • condensate generated and blowdown is periodically required. This excess blowdown condensate may be used to generate steam for thickener water DSI effectively dumping the blowdown condensate into the thickener water.
  • the steam may be generated by retrofitting a plant with a low pressure boiler or the like along with a thickener for recovering heat and water from the oil sand processing operation for recycling.
  • Retrofitting oil sand plants with a boiler and thickener enables the water recovered as thickener overflow to offset the water lost as condensate in DSI, in addition to the low quality heat recovery from the thickener.
  • Understanding of the overall plant allows matching appropriate steam and condensate streams with the DSI heating of thickener overflow water.
  • condensate that would otherwise be dumped is recycled as steam into the thickener water for heating and reuse in oil sand processing operations.
  • the DSI steam used for thickener water heating has a temperature between 140 to 215 °C and a pressure between 50 and 400 psia and may contain non-condensable gases such as carbon dioxide, air and the like that may be purged to maintain condensing steam heat exchangers.
  • the knock-out or steam trap system may be used to remove water from the steam, for example when above 10-15% water, and the removed water may be recycled back into the process.
  • the excess thickener overflow water 22 is thus heated by DSI units 26 that may be operated in series or parallel.
  • the arrangement of series or parallel DSI permits selective heating of excess thickener water to match specific temperature requirements for the end use of the steam heated process water.
  • the steam heated thickener water 28 supplied as froth under-wash 36 would be heated to the temperature needed for cleaning/heating the froth 34 separated in the sep cell 35.
  • the water treatment capacity to supply treated water 80 is increased to reflect the lost condensate associated with the portion of the steam injected as direct injection steam 88 into the DSI units.
  • the DSI heating of thickener overflow water for reuse in the oil sand extraction or bitumen production operation reduces capital as DSI unit have a lower cost compared to exchangers, improves reliability for instance due to no fouling of exchanger surfaces and recovery of both heat and water via the thickener.
  • Thickeners are prone to upsets leading to thickener water with variable compositions which can cause abrupt increases in solids or hydrocarbon content causing fouling of heat exchanger surfaces.
  • DSI allows robust heating of thickener overflow water to replace or offset conventional heat exchanged hot process water from recycle pond water.
  • the thickener water is provided about 20 S C to about 45 S C hotter than the ambient temperature of recycle water, since tailings ponds cool tailings water while allowing suspended solids to settle out to mature fine tailings.
  • overflow water from thickeners are further advantageous in this respect since the flow rates of the thickener overflow streams is sufficiently moderate that the increase make-up water required for the DSI heating is exceeded by the cost and efficiency savings achieved by the process of the present invention. Large volumes of water to be DSI heated would experience erosion of the cost advantage due to the increased make-up water to produce steam.
  • the thicker overflow DSI heating complements existing exchanger heating arrangements since the quantity of water produced by the thickener normally will not replace all the exchangers.
  • the water make-up 80 may be supplied from the recycle water system which would thus provide a closed loop on water usage, i.e. no net water import to the system. It is also noted that the DSI heating may be conducted in a manner as disclosed in Canadian patent application No. 2,735,31 1 (van der Merwe).
  • DSI units also rely on steam at pressures above the water pressure. Where this steam is produced by boilers that require high quality condensate for reliable operation, steam production is associated with significant utility infrastructure for the recovery of steam condensate and make-up water treatment. As DSI units can utilize purged steam with non-condensables without infrastructure to return condensate, the DSI provides an alternate process method for recovery and reuse of the energy in low quality steam and minimize costs associated with infrastructure.
  • the thickener 18' may be associated with a froth treatment operation 39 to thicken froth treatment tailings.
  • the bitumen froth 38 is fed to a dearator 89 and then to primary and secondary stage froth separation units 90, 92 which are arranged in a counter-current configuration.
  • Fresh solvent 94 which may be paraffinic or naphthenic is added to the second stage froth separation unit 92.
  • the high diluted bitumen 96 is treated in a solvent recovery unit which may include two flash vessels 98, 100 to produce recovered solvent 102 and solvent recovered bitumen 104.
  • the second stage froth separation unit 92 produces an underflow 106 that is solvent diluted tailings which are treated in a tailings solvent recovery unit which may include first and second stage flash or stripping vessels 108, 1 10 to recover solvent stream 1 1 1 . These stripping vessels 108, 1 10 may be fed with steam 1 12. The solvent recovered tailings 1 14 fro the second stage stripping vessel 1 10 may be provided as the warm tailings stream 16 to the thickener 18'.

Landscapes

  • Chemical & Material Sciences (AREA)
  • 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)

Abstract

L'invention concerne un procédé d'intégration de chaleur et d'eau destiné à une exploitation de sables bitumeux incluant la soumission de résidus de sables bitumeux chauds à un épaississement en vue de produire des résidus épaissis et une surverse d'eau chaude ; la soumission de la surverse d'eau chaude à une injection directe de vapeur (DSI) en vue de produire de l'eau de l'épaississeur, chauffée à la vapeur ; l'alimentation de l'eau de l'épaississeur, chauffée à la vapeur dans une unité de l'exploitation de sables bitumeux ; et la production de résidus de sables bitumeux chauds à partir de l'exploitation de sables bitumeux. L'unité d'exploitation de sables bitumeux peut être une unité de préparation de minerais de sables bitumeux et/ou une unité de séparation primaire par exemple. L'eau de l'épaississeur chauffée peut remplacer l'eau prise des stocks en bassin. La DSI peut utiliser l'excès de vapeur de faible qualité, humide, de basse pression et/ou de purge. Le procédé permet une utilisation améliorée de la chaleur et de l'eau dans le traitement des sables bitumeux.
PCT/CA2012/050287 2011-05-20 2012-05-02 Procédé d'intégration de chaleur et d'eau destiné à une exploitation de sables bitumeux comprenant une injection directe de vapeur à la surverse chaude de l'épaississeur Ceased WO2012159209A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US14/115,713 US20140076785A1 (en) 2011-05-20 2012-05-02 Heat and water integration process for an oil sand operation with direct steam injection of warm thickener overlfow

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
CA2740823A CA2740823C (fr) 2011-05-20 2011-05-20 Procede d'integration d'eau et de chaleur pour operation de sables bitumineux avec injection d'ecoulement direct de trop-plein d'agent epaississeur chaud
CA2.740.823 2011-05-20

Publications (1)

Publication Number Publication Date
WO2012159209A1 true WO2012159209A1 (fr) 2012-11-29

Family

ID=47215846

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/CA2012/050287 Ceased WO2012159209A1 (fr) 2011-05-20 2012-05-02 Procédé d'intégration de chaleur et d'eau destiné à une exploitation de sables bitumeux comprenant une injection directe de vapeur à la surverse chaude de l'épaississeur

Country Status (3)

Country Link
US (1) US20140076785A1 (fr)
CA (1) CA2740823C (fr)
WO (1) WO2012159209A1 (fr)

Families Citing this family (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8252170B2 (en) 2008-06-27 2012-08-28 Exxonmobil Upstream Research Company Optimizing feed mixer performance in a paraffinic froth treatment process
CA2650750C (fr) 2009-01-23 2013-08-27 Imperial Oil Resources Limited Methode et systeme pour determiner la distribution granulometrique et les solides pouvant etre filtres dans un fluide contenant du bitume
CA2672004C (fr) 2009-07-14 2012-03-27 Imperial Oil Resources Limited Materiel d'alimentation pour recipient de separation solides- liquides
CA2714842C (fr) 2010-09-22 2012-05-29 Imperial Oil Resources Limited Methode de surveillance de la qualite du bitume durant son extraction au moyen d'un solvant
CA2729457C (fr) 2011-01-27 2013-08-06 Fort Hills Energy L.P. Procede pour l'integration d'un centre de traitement de l'ecume paraffinique a une installation de forage et d'extraction de minerai bitumineux
CA2853070C (fr) 2011-02-25 2015-12-15 Fort Hills Energy L.P. Procede de traitement de bitume dilue a forte teneur en paraffine
CA2931815C (fr) 2011-03-01 2020-10-27 Fort Hills Energy L.P. Procede et unite pour la recuperation de solvant dans des residus dilues dans un solvant, provenant du traitement de la mousse de bitume
CA2806588C (fr) 2011-03-04 2014-12-23 Fort Hills Energy L.P. Procede pour l'ajout de solvant a la mousse de bitume avec melange en ligne et etapes de conditionnement
CA2735311C (fr) 2011-03-22 2013-09-24 Fort Hills Energy L.P. Procede pour un chauffage a injection de vapeur directe de la mousse de bitume des sables bitumineux
CA2815785C (fr) 2011-04-15 2014-10-21 Fort Hills Energy L.P. Recuperation de chaleur destinee a etre integree a une installation de traitement de mousse de bitume comprenant des circuits en boucle a circulation thermique
CA2738700C (fr) 2011-04-28 2013-11-19 Fort Hills Energy L.P. Ursr avec configurations de pulverisation d'admission pour la distribution des residus dilues par solvant
CA2738560C (fr) 2011-05-03 2014-07-08 Imperial Oil Resources Limited Amelioration du captage de fines particules dans le procede de traitement par moussage paraffinique
CA2739667C (fr) 2011-05-04 2015-07-07 Fort Hills Energy L.P. Procede de regulation de debit pour les operations de traitement de la mousse de bitume
CA2832269C (fr) 2011-05-18 2017-10-17 Fort Hills Energy L.P. Regulation de temperature pour un procede de traitement de mousse de bitume avec chauffage de compensation de courants de solvant
CN112877094A (zh) * 2021-01-12 2021-06-01 西南石油大学 一种油砂多级分离装置

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA1165712A (fr) * 1980-09-17 1984-04-17 Mario Dente Methode d'extraction
CA2123076A1 (fr) * 1994-05-06 1995-11-07 William Lester Strand Procede d'extraction de sables petroliferes
CA2524110A1 (fr) * 2005-10-21 2007-04-21 William L. Strand Methode de recuperation du bitume present dans les sables bitumineux
US20100147516A1 (en) * 2008-12-12 2010-06-17 Betzer-Zilevitch Maoz System and method for minimizing the negative enviromental impact of the oilsands industry
CA2752558A1 (fr) * 2010-09-13 2012-03-13 Maoz Betser-Zilevitch Appareil de generation de vapeur a contact direct exploite par vapeur

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7531096B2 (en) * 2005-12-07 2009-05-12 Arizona Public Service Company System and method of reducing organic contaminants in feed water
US8147682B2 (en) * 2006-10-31 2012-04-03 Syncrude Canada Ltd. Bitumen and thermal recovery from oil sand tailings
US8277614B2 (en) * 2008-09-29 2012-10-02 King Abdulaziz University Multi-stage flash desalination plant with feed cooler
CA2714766C (fr) * 2009-09-14 2014-07-15 Syncrude Canada Ltd. Puits d'alimentation pour recipient de separation par gravite

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA1165712A (fr) * 1980-09-17 1984-04-17 Mario Dente Methode d'extraction
CA2123076A1 (fr) * 1994-05-06 1995-11-07 William Lester Strand Procede d'extraction de sables petroliferes
CA2524110A1 (fr) * 2005-10-21 2007-04-21 William L. Strand Methode de recuperation du bitume present dans les sables bitumineux
US20100147516A1 (en) * 2008-12-12 2010-06-17 Betzer-Zilevitch Maoz System and method for minimizing the negative enviromental impact of the oilsands industry
CA2752558A1 (fr) * 2010-09-13 2012-03-13 Maoz Betser-Zilevitch Appareil de generation de vapeur a contact direct exploite par vapeur
CA2748477A1 (fr) * 2010-09-13 2012-03-13 Maoz Betzer Appareil de generation de vapeur a contact direct a entrainement par vapeur

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
SCHROYER, JAMES A..: "Understand the Basics of Steam Injection Heating.", CHEMICAL ENGINEERING PROGRESS, vol. 93, no. 5, May 1997 (1997-05-01), pages 52 - 55 *

Also Published As

Publication number Publication date
CA2740823A1 (fr) 2012-11-20
US20140076785A1 (en) 2014-03-20
CA2740823C (fr) 2015-08-25

Similar Documents

Publication Publication Date Title
CA2740823C (fr) Procede d'integration d'eau et de chaleur pour operation de sables bitumineux avec injection d'ecoulement direct de trop-plein d'agent epaississeur chaud
US8789608B2 (en) Steam generation process for enhanced oil recovery
US9114406B2 (en) Steam driven direct contact steam generation
CA2610052C (fr) Systeme et procede de recuperation thermique et hydrique, et production d'energie a partir de l'exploitation du bitume
JP6784455B2 (ja) 統合型原油ディーゼル水素処理及び芳香族施設における廃熱からの発電
US8166925B2 (en) Method and apparatus for steam generation
CA2752558C (fr) Appareil de generation de vapeur a contact direct exploite par vapeur
CA2610230C (fr) Integration d'eau entre une operation de recuperation in situ et l'extraction du bitume
US20110061610A1 (en) Heat and Water Recovery From Oil Sands Waste Streams
WO2009105309A1 (fr) Procédé et système de génération de vapeur dans l’industrie pétrolière
US20120279903A1 (en) Steam drive non-direct contact steam generation
US20140262258A1 (en) Steam generation method and method for recovering crude oil by steam-assisted gravity drainage (sagd) including said steam generation method
CN111807323A (zh) 一种蒸汽转化制氢的方法
CN102459514A (zh) 从油砂和页岩油中提取烃的方法
US20130233771A1 (en) System and method for minimizing the negative enviromental impact of the oilsands industry
WO2014085096A1 (fr) Procédé de traitement d'eau par vapeur surchauffée
CN110229689B (zh) 含固原料油的蒸馏装置及方法
CA2665747A1 (fr) Utilisation des boues excedentaires et des eaux a fins residus d'installations petrolieres pour l'obtention d'eau chaude et de vapeur destinees a la production de bitume
CN107144147B (zh) 一种基于余热利用的煅烧炉循环冷却系统及方法
CA2776389C (fr) Systeme de generation de vapeur a contact indirect
CN107166978A (zh) 一种基于余热回收的煅烧炉循环冷却系统及方法
CA2965581C (fr) Recuperation de chaleur a partir de residus de sable bitumineux au moyen d'un lit fluidise
US20160076760A1 (en) Method for generating steam from raw water, in particular from blow down water coming from a steam generator
US20120204962A1 (en) System and Method for Improved Hydrothermal Upgrading of Carbonaceous Material
CA2728064A1 (fr) Generation de vapeur par contact direct et entrainement par la vapeur

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 12789343

Country of ref document: EP

Kind code of ref document: A1

WWE Wipo information: entry into national phase

Ref document number: 14115713

Country of ref document: US

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 12789343

Country of ref document: EP

Kind code of ref document: A1