WO2010150234A2 - Procede de traitement d'hydrocarbures - Google Patents
Procede de traitement d'hydrocarbures Download PDFInfo
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- WO2010150234A2 WO2010150234A2 PCT/IB2010/052919 IB2010052919W WO2010150234A2 WO 2010150234 A2 WO2010150234 A2 WO 2010150234A2 IB 2010052919 W IB2010052919 W IB 2010052919W WO 2010150234 A2 WO2010150234 A2 WO 2010150234A2
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- Prior art keywords
- hydrocarbon
- phase
- line
- liquid
- unit
- Prior art date
Links
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 318
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 318
- 238000000034 method Methods 0.000 title claims abstract description 36
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 249
- 239000007788 liquid Substances 0.000 claims abstract description 138
- 239000012071 phase Substances 0.000 claims abstract description 128
- 239000002904 solvent Substances 0.000 claims abstract description 113
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 68
- ZQPPMHVWECSIRJ-KTKRTIGZSA-N oleic acid group Chemical group C(CCCCCCC\C=C/CCCCCCCC)(=O)O ZQPPMHVWECSIRJ-KTKRTIGZSA-N 0.000 claims abstract description 54
- 238000004064 recycling Methods 0.000 claims abstract description 33
- 239000008346 aqueous phase Substances 0.000 claims abstract description 16
- 150000001335 aliphatic alkanes Chemical class 0.000 claims abstract description 11
- 238000000926 separation method Methods 0.000 claims description 89
- 238000004519 manufacturing process Methods 0.000 claims description 32
- 238000011084 recovery Methods 0.000 claims description 25
- 230000008569 process Effects 0.000 claims description 24
- 230000005484 gravity Effects 0.000 claims description 22
- 239000007787 solid Substances 0.000 claims description 16
- 238000009434 installation Methods 0.000 claims description 15
- 238000011282 treatment Methods 0.000 claims description 14
- 230000006835 compression Effects 0.000 claims description 9
- 238000007906 compression Methods 0.000 claims description 9
- 238000007872 degassing Methods 0.000 claims description 8
- 230000015572 biosynthetic process Effects 0.000 claims description 7
- 238000000605 extraction Methods 0.000 claims description 7
- 239000000654 additive Substances 0.000 claims description 4
- 230000000996 additive effect Effects 0.000 claims description 4
- 239000011343 solid material Substances 0.000 claims description 2
- 230000032258 transport Effects 0.000 description 27
- 239000003921 oil Substances 0.000 description 25
- 239000008186 active pharmaceutical agent Substances 0.000 description 19
- 239000000295 fuel oil Substances 0.000 description 14
- 239000007789 gas Substances 0.000 description 14
- 239000000203 mixture Substances 0.000 description 13
- 238000010438 heat treatment Methods 0.000 description 11
- 150000001875 compounds Chemical class 0.000 description 7
- 238000007670 refining Methods 0.000 description 5
- -1 C20 hydrocarbons Chemical class 0.000 description 4
- 238000004821 distillation Methods 0.000 description 4
- 238000005086 pumping Methods 0.000 description 4
- 238000011144 upstream manufacturing Methods 0.000 description 4
- 239000012043 crude product Substances 0.000 description 3
- 239000000839 emulsion Substances 0.000 description 3
- 239000003915 liquefied petroleum gas Substances 0.000 description 3
- 239000002245 particle Substances 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- 230000008016 vaporization Effects 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 238000001816 cooling Methods 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 238000011033 desalting Methods 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 239000007792 gaseous phase Substances 0.000 description 2
- 238000002156 mixing Methods 0.000 description 2
- 238000001556 precipitation Methods 0.000 description 2
- 238000004062 sedimentation Methods 0.000 description 2
- 238000009834 vaporization Methods 0.000 description 2
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 1
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 125000004432 carbon atom Chemical group C* 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000004581 coalescence Methods 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 230000000368 destabilizing effect Effects 0.000 description 1
- 238000005243 fluidization Methods 0.000 description 1
- 239000008240 homogeneous mixture Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 230000010354 integration Effects 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 238000010587 phase diagram Methods 0.000 description 1
- 238000005191 phase separation Methods 0.000 description 1
- 239000000047 product Substances 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000005507 spraying Methods 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
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
- C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
- C10G21/06—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents characterised by the solvent used
- C10G21/12—Organic compounds only
- C10G21/14—Hydrocarbons
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G21/00—Refining of hydrocarbon oils, in the absence of hydrogen, by extraction with selective solvents
- C10G21/28—Recovery of used solvent
-
- 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
- C10G33/00—Dewatering or demulsification of hydrocarbon oils
- C10G33/04—Dewatering or demulsification of hydrocarbon oils with chemical means
-
- 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
- C10G2300/10—Feedstock materials
- C10G2300/1033—Oil well production fluids
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/20—Characteristics of the feedstock or the products
- C10G2300/30—Physical properties of feedstocks or products
- C10G2300/308—Gravity, density, e.g. API
-
- 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
- C10G2300/4081—Recycling aspects
-
- 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
Definitions
- the present invention relates to a process for treating hydrocarbons, in particular for reducing the water content of a hydrocarbon stream, and an installation adapted to the implementation of this process.
- Hydrocarbons extracted from tanks must generally be processed before being stored and / or transported to the refineries where they are recovered.
- One of the main treatments is to remove the production water that is mixed with hydrocarbons. This treatment is generally carried out by gravitational separation, optionally supplemented by electrostatic coalescence.
- naphtha is generally used, which is a hydrocarbon fraction mainly comprising C6 to C20 hydrocarbons.
- This solvent makes it possible to increase the API degree of the hydrocarbons to be treated, typically up to a value of approximately 20 at most (in the case of heavy oils).
- the solvent is generally recycled by a distillation process at the level of the upgrading unit, then brought back to the production site in a pipe in the opposite direction to the main pipe carrying the hydrocarbons produced.
- Naphtha is used for its good compatibility with heavy oils, making it possible to have a homogeneous mixture, and in order to avoid the risks of two-phase separation or creation of deposit during transportation to the recovery unit.
- the document WO 99/1 9425 describes a process for upgrading heavy oils which is more particularly intended for hydrocarbons recovered from mining residues, containing a high solids content.
- a hydrocarbon solvent is added to heavy oils.
- the separation of the water as such is carried out in part by means of a flash expansion of the mixture of heavy oils and the hydrocarbon solvent (consisting of vaporizing a part of the hydrocarbons and water) and in addition by means of a hydrocyclone.
- This scheme is based on the precipitation of certain hydrocarbon compounds using the solvents used. This is a very complex scheme.
- the invention relates firstly to a process for the treatment of hydrocarbons, said process comprising: providing an initial hydrocarbon stream comprising water; adding a liquid solvent to the initial hydrocarbon stream to provide an intermediate hydrocarbon stream, said liquid solvent comprising a mass proportion of C3 to C6 alkanes greater than or equal to 80%;
- the initial hydrocarbon stream has a degree
- API between 5 and 25 and the intermediate hydrocarbon stream has a degree
- the liquid solvent comprises a mass proportion of C3 and C4 alkanes greater than or equal to 80%, preferably greater than or equal to 85%, more preferably greater than or equal to 90%, most preferably greater than or equal to 95%.
- the recycling of the gaseous hydrocarbon phase to at least partly provide the liquid solvent comprises the compression of the gaseous hydrocarbon phase and optionally an addition of liquid solvent.
- the step of supplying the initial hydrocarbon stream comprises: extracting hydrocarbons from a subterranean formation;
- the initial hydrocarbon stream comprises less than 20,000 ppm solids, preferably less than 1,000 ppm solids, more preferably less than 5,000 ppm solids, in mass proportion.
- the gravitational separation of the intermediate hydrocarbon stream is carried out at a pressure of between 3 and 15 bar, preferably between 5 and 10 bar; and or the separation of the oleic phase into the gaseous hydrocarbon phase and the liquid hydrocarbon phase is carried out at a pressure of between 1 and 3 bar, preferably between 1 and 2 bar.
- the above-mentioned method furthermore comprises: the transport of the liquid hydrocarbon phase followed by the recovery of the liquid hydrocarbon phase; or
- the invention furthermore relates to a hydrocarbon treatment plant comprising:
- a hydrocarbon flow feed line a liquid solvent supply line opening into the hydrocarbon flow supply line;
- a liquid / gas separation unit fed by the oleic phase withdrawal line; a gaseous hydrocarbon phase withdrawal line and a liquid hydrocarbon phase withdrawal line connected at the outlet of the liquid / gas separation unit;
- the gaseous hydrocarbon phase withdrawal line supplying a liquid solvent recycling line, said liquid solvent recycling line at least partially supplying the liquid solvent supply line.
- the aforementioned installation comprises compression means on the gaseous hydrocarbon phase withdrawal line, and in which the liquid solvent supply line is fed by the liquid solvent recycling line and by a booster line of liquid solvent.
- the aforementioned installation comprises:
- the aforementioned installation comprises:
- an intermediate unit comprising the water / hydrocarbon gravity separation unit
- the intermediate unit comprises the liquid / gas separation unit, the installation possibly also comprising an additive supply line opening into the second hydrocarbon transport pipe, and:
- the solvent recycle line is included in the intermediate unit; or - the liquid solvent recycling line is derived from the intermediate unit and opens into the first hydrocarbon transport pipe.
- the recovery unit comprises the liquid / gas separation unit, and:
- the liquid solvent recycling line comes from the recovery unit and feeds the intermediate unit;
- the liquid solvent recycling line comes from the upgrading unit and opens into the first hydrocarbon transport pipe.
- the aforementioned method is implemented in an installation as described above.
- the present invention overcomes the disadvantages of the state of the art.
- it provides a hydrocarbon treatment process for effecting oil / water separation more efficiently, simpler, more economical and faster than in existing processes, especially for heavy oils.
- This is accomplished through the use of a mild C 3 -C 6 alkane solvent (preferably based on C 3 and C 4 alkanes), which is mixed with the hydrocarbons so as to significantly increase the degree of API of these last.
- a mild C 3 -C 6 alkane solvent preferably based on C 3 and C 4 alkanes
- the light solvent can then be easily recovered (separated from the hydrocarbons to which it has been mixed) without the need for distillation, and thus recycled.
- the invention also has one or preferably more of the advantageous features listed below.
- the size of the water / oil separators can be reduced, compared to the state of the art in which naphtha is mixed with the crude product before the water / oil separation.
- the heating requirements are reduced to the stage of the water / oil separation, compared to the state of the art in which naphtha is mixed with the crude product before the water / oil separation.
- the API degree of the hydrocarbons is increased more significantly than in the state of the art in which naphtha is mixed with the crude product before the water / oil separation, which increases the water / oil separation rate.
- the residence time in the separators can be reduced to a few minutes instead of one or more hours.
- the recovery of the solvent can be carried out in a simple manner, at a pressure close to atmospheric pressure, and without the use of a distillation column.
- the solvent is recycled with a minimum of losses (the losses are in particular reduced compared to the conventional scheme).
- the solvent can also be used to fluidize the hydrocarbons and facilitate their transport, between the production site and the water / oil separation unit and / or between the water / oil separation unit and the oil / water separation unit. valuation unit.
- the invention provides a much simpler process and installation for the treatment of hydrocarbons, the water being in particular eliminated by a simple gravitational separation and without resorting to partial vaporization.
- FIG. 1 schematically shows an embodiment of the hydrocarbon treatment plant according to the invention.
- Figures 2 to 5 schematically show four alternative embodiments of the hydrocarbon processing plant according to the invention.
- upstream and downstream are defined with respect to the direction of transport of the different fluids in the installation.
- a hydrocarbon treatment plant according to the invention comprises a hydrocarbon stream feed line 1.
- the hydrocarbon stream to be treated arrives via this hydrocarbon stream feed line 1. It can include a liquid phase and a gaseous phase, and it contains water.
- Gas degassing means 2 can be provided on the hydrocarbon flow feed line 1.
- a gas withdrawal line 3 is then connected at the outlet of the degassing means 2.
- a majority of the gaseous phase of the hydrocarbon stream can be removed at this stage, if necessary.
- the degassing means 2 may comprise a (or play the role of a) "slug catcher", that is to say, provide a function to prevent plugs or overpressures from passing to the subsequent levels of the process.
- pumping means 4 may be provided on the hydrocarbon flow line 1, downstream of the degassing means 2, to compress the hydrocarbon stream if necessary.
- the plant according to the invention also comprises a liquid solvent supply line 5, which opens into the hydrocarbon flow feed line 1.
- a liquid solvent supply line 5 which opens into the hydrocarbon flow feed line 1.
- a static or motorized mixer can be provided to ensure mixing of the fluids from these two lines, but generally it is not necessary.
- the liquid solvent is itself based on hydrocarbons and it comprises a mass proportion of C 3 to C 6 alkanes greater than or equal to 80%, preferably greater than or equal to 85%, more preferably greater than or equal to 90% and ideally greater than or equal to 95%.
- the liquid solvent comprises a mass proportion of C 3 and C 4 alkanes greater than or equal to 80%, preferably greater than or equal to 85%, more preferably greater than or equal to 90%, and ideally greater than or equal to 95%.
- This liquid solvent is therefore generally of the LPG (liquefied petroleum gas) type.
- the liquid solvent comprises a mass proportion of C5 and C6 alkanes greater than or equal to 80%, preferably greater than or equal to 85%, more preferably greater than or equal to 90%, and ideally greater than or equal to 95%.
- the initial hydrocarbon stream is generally a so-called heavy or extra heavy oil. Preferably, this initial hydrocarbon stream has a degree API of between 5 and 25.
- API degree can be measured according to ASTM D287.
- the addition of liquid solvent makes it possible to considerably increase the API degree; and the intermediate hydrocarbon stream preferably has a degree API greater than or equal to 30, more preferably greater than or equal to 35, ideally greater than or equal to 40.
- the alkanes C1 and C2 are very light, and it would be necessary to work at very cold temperatures or very high pressures to be able to dispose of it in liquid form, which is essential to be able to mix with the flow hydrocarbon initial to increase the API degree.
- the molar ratio of hydrocarbon proportions of the initial hydrocarbon stream and hydrocarbons of the liquid solvent is chosen so as to obtain the desired API degree in the intermediate hydrocarbon stream. This molar ratio is also adjusted according to the risk of precipitation by asphaltene deposition.
- this molar ratio is between 0.2 and 5, preferably between 0.5 and 2, especially between 0.8 and 1, 25, and ideally is close to 1. This corresponds to a much lower proportion by weight of solvent. to what is used in the state of the art with naphtha solvents.
- composition of the liquid solvent may be chosen according to the constraints of the process or, preferably , can itself be considered as a constraint (for example because one has a determined LPG stream readily available as part of the overall hydrocarbon production and processing process).
- other parameters of the process are adjusted according to this stress (ratio of the molar proportions of hydrocarbons of the initial hydrocarbon stream and hydrocarbon liquid solvent, temperature and operating pressure ).
- the intermediate hydrocarbon stream via the hydrocarbon stream feed line 1, enters a gravity separation unit water / hydrocarbons 6.
- gravity separation unit water / hydrocarbons means any set of means likely to separating a mixture of water and liquid hydrocarbons in an aqueous phase and an oleic phase, by the action of gravity, the aqueous phase being denser than the oleic phase.
- the water / hydrocarbon gravity separation unit 6 is not a unit capable of effecting a water / hydrocarbon separation by vaporization (flash expansion). This is advantageous because sudden pressure changes are counterproductive for a water / hydrocarbon separation; indeed they induce a strong shear which tends to recreate emulsions. In the context of the process according to the invention, it is therefore work at constant or almost constant pressure during the water / hydrocarbon separation.
- the water / hydrocarbon gravity separation unit 6 may comprise any separator known to those skilled in the art, with or without means for destabilizing the emulsions, such as means for spraying the oil / water interface, and with or without heating means.
- the water / hydrocarbon gravity separation unit 6 may for example be an apparatus as described in WO 2005/100512.
- the water / hydrocarbon gravity separation unit 6 may comprise desalting means.
- the desalting means typically comprise at least two successive separators, with a demineralized water supply line between the separators.
- the gravitational separation carried out within the gravity separation unit water / hydrocarbons 6 is generally carried out at a pressure of between 3 and 15 bar, preferably between 5 and 10 bar, for example between 7 and 8 bar (all the values of pressure mentioned in the present application are absolute values).
- a pressure of between 3 and 15 bar preferably between 5 and 10 bar, for example between 7 and 8 bar (all the values of pressure mentioned in the present application are absolute values).
- it is unnecessary to heat the initial hydrocarbon stream or the intermediate hydrocarbon stream or to provide heating during the gravity separation because the mixture of the initial hydrocarbon stream with the liquid solvent makes it possible to increase sufficiently the API degree of the hydrocarbons so that the gravitational separation is carried out quickly and efficiently without heating (one operates then at ambient temperature).
- the gravity separation provides an oleic phase and an aqueous phase, which are respectively withdrawn into an oleic phase withdrawal line 8 and an aqueous phase withdrawal line 7.
- the aqueous phase is generally subjected to further treatment before being, for example, discharged into the environment or reused as part of the overall hydrocarbon production process.
- the quality of the water is better than in the processes of the state of the art: the aqueous phase contains a lower proportion of hydrocarbons and a lower proportion of solid particles (because the solid particles decant and therefore are eliminated more easily during the hydrocarbon / water separation, because of the relatively high fluidity of the hydrocarbons). Therefore, the subsequent treatment of the aqueous phase may be smaller and simpler than in the state of the art.
- the oleic phase is then subjected to a separation step in a gaseous hydrocarbon phase and a liquid hydrocarbon phase, in a liquid / gas separation unit 12, supplied by the oleic phase withdrawal line.
- the gaseous hydrocarbon phase is withdrawn by means of a gaseous hydrocarbon phase withdrawal line 14 and the liquid hydrocarbon phase is withdrawn by a liquid hydrocarbon phase withdrawal line 13.
- the oleic phase has essentially the same chemical composition as the intermediate hydrocarbon stream (mixture of the initial hydrocarbon stream and the liquid solvent), with the exception of the water content.
- the gaseous hydrocarbon phase resulting from the separation in the liquid / gas separation unit 12 has essentially the same chemical composition as the liquid solvent.
- the liquid hydrocarbon phase, from the liquid / gas separation unit 12, has essentially the same chemical composition as the initial hydrocarbon stream (with the exception of the water content).
- the separation of the oleic phase into the gaseous hydrocarbon phase and the liquid hydrocarbon phase essentially amounts to separating again the intermediate hydrocarbon stream (of high degree API) on the one hand the flow of hydrocarbon initial (low degree API) free of the majority of its water, and secondly the hydrocarbon composition comprising predominantly C3 to C6 alkanes (especially C3 and C4 according to one embodiment), which constitutes the solvent liquid, to ensure recycling of this composition.
- this separation step makes it possible to recover, in the form of the gaseous hydrocarbon phase, more than 50%, preferably more than 75%, more particularly preferably more than 85%, ideally more than 90%, even more than 95%, in molar proportion, of hydrocarbons supplied by the solvent liquid.
- it is not essential to recover all of these compounds, especially when the liquid hydrocarbon phase undergoes subsequent recovery and / or refining steps during which the remaining fraction of the added compounds can be isolated.
- the oleic phase resulting from the gravity separation water / hydrocarbons is expanded by means of expansion means 9 provided on the withdrawal line. oleic phase 8.
- the pressure of the oleic phase is reduced to between 1 and 3 bar, preferably between 1 and 2 bar for the purposes of separating the oleic phase into the gaseous hydrocarbon phase and the liquid hydrocarbon phase.
- the separation is carried out all the better that the pressure is low, however, it is generally not recommended to carry out the separation exactly at atmospheric pressure (1 bar), as this complicates the subsequent recompression of the phase of gaseous hydrocarbons.
- the oleic phase can also be heated if necessary, prior to separation or during separation, by means of heating means 10, 11. It is for example possible to provide a main heating by external heating means 1 1, preceded a preliminary heating by a heat exchanger 10, against the cooling of the liquid hydrocarbon phase from the separation step.
- temperature and pressure conditions (as well as the molar ratio of the hydrocarbon proportions of the initial hydrocarbon stream and the hydrocarbons of the liquid solvent) are chosen so that:
- the solvent added to the initial hydrocarbon stream is in the liquid state, and remains in the liquid state during the gravity separation water / hydrocarbons;
- this solvent is in the gaseous state during the separation of the oleic phase. This choice of conditions is carried out simply by studying the phase diagram of the solvent.
- the gaseous hydrocarbon phase is recycled to at least partially provide the aforementioned liquid solvent, which involves compressing and liquefying this phase.
- the gaseous hydrocarbon phase withdrawal line 14 feeds a liquid solvent recycling line 23, said liquid solvent recycling line 23 in turn supplying, at least partially, the solvent supply line. liquid 5.
- Compression means 16, 18 are provided on the gaseous hydrocarbon phase withdrawal line 14, with cooling means 17, 19 at the output of each compressor or compressor stage.
- One or more compression stages are to be considered but preferably a single compression stage.
- a separating element 15 may also be provided on the gaseous hydrocarbon phase withdrawal line 14. This separation element 15, upstream of the compression means 16, 18, protects the latter, because these compression means 16, 18 must compress only gases.
- Pumping means 22 are also provided on the liquid solvent recycling line 23.
- a separating element 20 may be provided upstream of the pumping means 22, in order to protect them, since the pumping means 22 must compress only liquids.
- liquid solvent booster can be carried out.
- the liquid solvent supply line 5 can be supplied both by the liquid solvent recycling line 23 and by a liquid solvent booster line 24.
- the invention can be implemented in the context of the production of hydrocarbons, especially oil.
- the plant according to the invention comprises hydrocarbon extraction means in an underground formation, and the supply of the initial hydrocarbon stream comprises the extraction of hydrocarbons from the underground formation.
- the initial hydrocarbon stream is thus a crude oil stream.
- no product or compound is added to the hydrocarbons between the extraction of the subterranean formation and the step of adding the liquid solvent.
- the hydrocarbon extraction means may for example comprise a set of wells (or "cluster").
- the initial hydrocarbon stream which is fed to the water / hydrocarbon gravity separation unit 6 via the hydrocarbon stream feed line 1, preferably contains less than 20,000 ppm solids (by mass), more preferably, less than 10,000 ppm solids, and most preferably less than 5,000 ppm solids.
- the water / hydrocarbon gravity separation unit 6 may conventionally include solids removal means to further reduce the solids content in the subsequent process.
- the plant according to the invention generally comprises: a hydrocarbon production unit 101;
- the hydrocarbon production unit 101 comprises in particular the aforementioned hydrocarbon extraction means. It can be on land or off-shore.
- Intermediate unit 103 comprises a set of treatment means, and in particular the water / hydrocarbon gravity separation unit 6. It may be on land or off-shore (underwater or on the surface).
- the hydrocarbon recovery unit 105 (located on land) is suitable for upgrading hydrocarbons (that is to say to achieve their "upgrading").
- This hydrocarbon recovery unit 105 comprises a set of means for converting hydrocarbons into lighter compounds. It may comprise refining means or conversion means prior to refining.
- the hydrocarbons are conveyed by a first hydrocarbon transport pipe 102.
- the hydrocarbons are conveyed by a second hydrocarbon transport pipe 104.
- the distance between the hydrocarbon production unit 101 (or certain sites of the hydrocarbon production unit 101, when this is geographically extended) and the intermediate unit 103 may be greater than 1 km, or even greater to 1 0 km and even more than 1 00 km. Likewise, the distance between the intermediate unit 103 and the hydrocarbon recovery unit 105 may be greater than 1 km, even greater than 10 km and even greater than 100 km.
- the intermediate unit 103 comprises the liquid / gas separation unit 12 and the liquid solvent recycling line 106.
- the flow hydrocarbon feedstock is mixed with the liquid solvent, the intermediate hydrocarbon stream is separated into an oleic phase and an aqueous phase, the oleic phase is expanded and separated into a gaseous hydrocarbon phase and a liquid hydrocarbon phase and that the gaseous hydrocarbon phase is recycled to partially supply the liquid solvent.
- the intermediate unit 103 It is therefore within the intermediate unit 103 that the initial hydrocarbon stream is mixed with the liquid solvent, that the intermediate hydrocarbon stream is separated into an oleic phase and an aqueous phase. Then, it is within the hydrocarbon recovery unit 105 that the oleic phase is expanded and separated into a gaseous hydrocarbon phase and a liquid hydrocarbon phase, and that the gaseous hydrocarbon phase is recycled. to partially supply the liquid solvent. The liquid solvent is then returned to the intermediate unit 103. In this embodiment, the second hydrocarbon transport pipe 104 merges with the oleic phase withdrawal line 8.
- a third embodiment represented in FIG. 4, all the means described above allowing the separation of the oil and the water as well as the supply, the circulation and the recycling of the liquid solvent are distributed. between the intermediate unit 103 and the hydrocarbon production unit 110. More specifically, the gravitational separation is carried out in the intermediate unit 103, as well as the recovery of the compounds forming the liquid solvent (the intermediate unit 103 comprising the liquid / gas separation unit 12).
- the liquid solvent recycling line 106 then exits the intermediate unit 103 and opens into the hydrocarbon production unit 101 (preferably at the wellhead) or in the first hydrocarbon transport line 102. (preferably towards the beginning of this pipe, that is to say at the outlet of the hydrocarbon production unit 101).
- the initial hydrocarbon stream is mixed with the liquid solvent.
- the intermediate hydrocarbon stream is separated into an oleic phase and an aqueous phase, the oleic phase is expanded and separated into a gaseous hydrocarbon phase and a hydrogen phase. liquid hydrocarbons, and that the gaseous hydrocarbon phase is recycled to partially supply the liquid solvent.
- the liquid solvent is then returned to the hydrocarbon production unit 101.
- the first conduit Hydrocarbon transport 102 essentially transports the intermediate hydrocarbon stream described above.
- a fourth embodiment represented in FIG. 5, all the means described above allowing the separation of the oil and the water as well as the circulation and the recycling of the liquid solvent are distributed between the unit hydrocarbon production plant 101, the intermediate unit 103 and the upgrading unit 105. More specifically, the liquid solvent is mixed with the initial hydrocarbon stream at the outlet of the hydrocarbon production unit 101, the gravitational separation is carried out in the intermediate unit 103 and the recovery of the compounds forming the liquid solvent is carried out in the upgrading unit 105 (which comprises the liquid / gas separation unit 12).
- the liquid solvent recycling line 106 then leaves the upgrading unit 105 and opens into the hydrocarbon production unit 101 (preferably at the wellhead), or in the first conveying line hydrocarbons 102 (preferably towards the beginning of this pipe, that is to say at the outlet of the hydrocarbon production unit 101).
- the initial hydrocarbon stream is mixed with the liquid solvent.
- the intermediate unit 103 that the intermediate hydrocarbon stream is separated into an oleic phase and an aqueous phase.
- the upgrading unit 105 it is within the upgrading unit 105 that the oleic phase is expanded and separated into a gaseous hydrocarbon phase and a liquid hydrocarbon phase, and that the gaseous hydrocarbon phase is recycled to provide partially the liquid solvent.
- the liquid solvent is then returned to the hydrocarbon production unit 101.
- the first hydrocarbon transport conduit 102 essentially transports the intermediate hydrocarbon stream described above.
- the second hydrocarbon transport pipe 104 merges with the oleic phase withdrawal line 8.
- FIGS. 3 and 5 have the advantage of facilitating the transport of hydrocarbons in the second hydrocarbon transport pipe 104 to the upgrading unit 105, since the hydrocarbon stream is mixed at this stage with the liquid solvent, which significantly reduces its viscosity.
- fluidization means for the hydrocarbons flowing in the second hydrocarbon transport pipe 104.
- These may be heating means and / or an additive feed line 107 opening into the second hydrocarbon transport pipe 104 and allowing the injection into the hydrocarbons of a viscosity reduction additive (or DRA) of the type surfactant combined with a hydrocarbon composition of low or moderate API degree, or even only a hydrocarbon composition of low or moderate API degree, such as naphtha for example.
- FIGS. 4 and 5 have the advantage of facilitating the transport of the hydrocarbons in the first hydrocarbon transport pipe 102 to the intermediate unit 103, since the hydrocarbon stream is mixed at this stage with the liquid solvent, which significantly reduces its viscosity.
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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
Description
Claims
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GB1121967.2A GB2483039B (en) | 2009-06-26 | 2010-06-25 | Method for treating hydrocarbons |
NO20120010A NO20120010A1 (no) | 2009-06-26 | 2012-01-06 | Fremgangsmate for behandling av hydrokarboner |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
FR0903116 | 2009-06-26 | ||
FR0903116A FR2947281B1 (fr) | 2009-06-26 | 2009-06-26 | Procede de traitement d'hydrocarbures |
Publications (2)
Publication Number | Publication Date |
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WO2010150234A2 true WO2010150234A2 (fr) | 2010-12-29 |
WO2010150234A3 WO2010150234A3 (fr) | 2011-03-17 |
Family
ID=41831510
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/IB2010/052919 WO2010150234A2 (fr) | 2009-06-26 | 2010-06-25 | Procede de traitement d'hydrocarbures |
Country Status (4)
Country | Link |
---|---|
FR (1) | FR2947281B1 (fr) |
GB (1) | GB2483039B (fr) |
NO (1) | NO20120010A1 (fr) |
WO (1) | WO2010150234A2 (fr) |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO1999019425A1 (fr) | 1997-10-15 | 1999-04-22 | Unipure Corporation | Procede permettant d'ameliorer la production de petrole brut lourd |
WO2005100512A1 (fr) | 2004-04-15 | 2005-10-27 | Total S.A. | Procede de traitement de petrole brut, procede de separation d'une emulsion eau dans l'huile d'hydrocarbure et appareils permettant de mettre en oeuvre ceux-ci |
Family Cites Families (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2383362A (en) * | 1940-08-17 | 1945-08-21 | United Gas Improvement Co | Separation of hydrocarbon emulsions |
US2383363A (en) * | 1943-02-27 | 1945-08-21 | United Gas Improvement Co | Chemical process |
US2462593A (en) * | 1945-08-17 | 1949-02-22 | United Gas Improvement Co | Pitch resin |
GB2335436B (en) * | 1998-03-04 | 2002-05-15 | Olim Technologies Sa | Method of refining waste oil |
DE10311289A1 (de) * | 2003-03-14 | 2004-09-23 | Minitec Engineering Gmbh | Verfahren zur Aufbereitung von Öl-Wasser-Emulsionen |
CA2435113C (fr) * | 2003-07-11 | 2008-06-17 | Her Majesty The Queen In Right Of Canada As Represented By The Minister Of Natural Resources Canada | Procede de traitement d'emulsions d'huiles lourdes au moyen d'un melange de naphtha et d'hydrocarbure aliphatique leger |
EP1783101A1 (fr) * | 2005-11-03 | 2007-05-09 | M-I Epcon As | Procédé et installation pour la purification de l'eau |
-
2009
- 2009-06-26 FR FR0903116A patent/FR2947281B1/fr active Active
-
2010
- 2010-06-25 WO PCT/IB2010/052919 patent/WO2010150234A2/fr active Application Filing
- 2010-06-25 GB GB1121967.2A patent/GB2483039B/en not_active Expired - Fee Related
-
2012
- 2012-01-06 NO NO20120010A patent/NO20120010A1/no not_active Application Discontinuation
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO1999019425A1 (fr) | 1997-10-15 | 1999-04-22 | Unipure Corporation | Procede permettant d'ameliorer la production de petrole brut lourd |
WO2005100512A1 (fr) | 2004-04-15 | 2005-10-27 | Total S.A. | Procede de traitement de petrole brut, procede de separation d'une emulsion eau dans l'huile d'hydrocarbure et appareils permettant de mettre en oeuvre ceux-ci |
Also Published As
Publication number | Publication date |
---|---|
FR2947281A1 (fr) | 2010-12-31 |
GB201121967D0 (en) | 2012-02-01 |
FR2947281B1 (fr) | 2012-11-16 |
GB2483039A (en) | 2012-02-22 |
NO20120010A1 (no) | 2012-01-06 |
WO2010150234A3 (fr) | 2011-03-17 |
GB2483039B (en) | 2013-07-10 |
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