CN103096989B - Relate to the improvement that hydrocarbon reclaims - Google Patents
Relate to the improvement that hydrocarbon reclaims Download PDFInfo
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- CN103096989B CN103096989B CN201180043778.5A CN201180043778A CN103096989B CN 103096989 B CN103096989 B CN 103096989B CN 201180043778 A CN201180043778 A CN 201180043778A CN 103096989 B CN103096989 B CN 103096989B
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- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 108
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 108
- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 103
- 230000006872 improvement Effects 0.000 title description 3
- 239000000203 mixture Substances 0.000 claims abstract description 109
- 150000003839 salts Chemical class 0.000 claims abstract description 62
- 238000000034 method Methods 0.000 claims abstract description 55
- 239000004094 surface-active agent Substances 0.000 claims abstract description 52
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 50
- 239000007864 aqueous solution Substances 0.000 claims abstract description 32
- 239000000839 emulsion Substances 0.000 claims abstract description 31
- 239000012071 phase Substances 0.000 claims description 82
- 239000008346 aqueous phase Substances 0.000 claims description 23
- 239000000126 substance Substances 0.000 claims description 17
- 238000010612 desalination reaction Methods 0.000 claims description 16
- 238000011084 recovery Methods 0.000 claims description 11
- 238000001728 nano-filtration Methods 0.000 claims description 9
- 238000005191 phase separation Methods 0.000 claims description 8
- 230000015572 biosynthetic process Effects 0.000 claims description 7
- 238000005406 washing Methods 0.000 claims description 7
- 238000001223 reverse osmosis Methods 0.000 claims description 6
- 230000001105 regulatory effect Effects 0.000 claims description 5
- 238000005728 strengthening Methods 0.000 claims description 3
- 239000003921 oil Substances 0.000 description 41
- 239000004530 micro-emulsion Substances 0.000 description 13
- 238000005516 engineering process Methods 0.000 description 10
- 230000015556 catabolic process Effects 0.000 description 8
- 230000008569 process Effects 0.000 description 8
- 239000000919 ceramic Substances 0.000 description 5
- 239000012528 membrane Substances 0.000 description 5
- 239000006184 cosolvent Substances 0.000 description 4
- 238000011033 desalting Methods 0.000 description 4
- 238000004945 emulsification Methods 0.000 description 4
- 230000008901 benefit Effects 0.000 description 3
- 239000010779 crude oil Substances 0.000 description 3
- 238000010586 diagram Methods 0.000 description 3
- 239000007788 liquid Substances 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 2
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 2
- 239000000654 additive Substances 0.000 description 2
- 230000000996 additive effect Effects 0.000 description 2
- 229910052799 carbon Inorganic materials 0.000 description 2
- 150000001768 cations Chemical class 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 239000004064 cosurfactant Substances 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 230000002209 hydrophobic effect Effects 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000001471 micro-filtration Methods 0.000 description 2
- 229920000435 poly(dimethylsiloxane) Polymers 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 238000012545 processing Methods 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- 238000007670 refining Methods 0.000 description 2
- 230000000717 retained effect Effects 0.000 description 2
- 239000012266 salt solution Substances 0.000 description 2
- 238000000926 separation method Methods 0.000 description 2
- 238000000108 ultra-filtration Methods 0.000 description 2
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 1
- 239000004642 Polyimide Substances 0.000 description 1
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 1
- 239000005864 Sulphur Substances 0.000 description 1
- 229910010413 TiO 2 Inorganic materials 0.000 description 1
- 230000003213 activating effect Effects 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 239000011324 bead Substances 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 230000001276 controlling effect Effects 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
- 230000020335 dealkylation Effects 0.000 description 1
- 238000006900 dealkylation reaction Methods 0.000 description 1
- 238000007865 diluting Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 229910052736 halogen Inorganic materials 0.000 description 1
- 150000002367 halogens Chemical class 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 125000004435 hydrogen atom Chemical group [H]* 0.000 description 1
- 238000001764 infiltration Methods 0.000 description 1
- -1 kerogen (kerogen) Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 150000002894 organic compounds Chemical class 0.000 description 1
- 239000012074 organic phase Substances 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 235000020030 perry Nutrition 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000004391 petroleum recovery Methods 0.000 description 1
- 229920001721 polyimide Polymers 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 229920006254 polymer film Polymers 0.000 description 1
- 235000011164 potassium chloride Nutrition 0.000 description 1
- 239000001103 potassium chloride Substances 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 238000009938 salting Methods 0.000 description 1
- 239000013535 sea water Substances 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000013589 supplement Substances 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
- 238000012546 transfer Methods 0.000 description 1
- 230000000007 visual effect Effects 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
- C10G33/00—Dewatering or demulsification of hydrocarbon oils
- C10G33/04—Dewatering or demulsification of hydrocarbon oils with chemical means
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
- B01D17/02—Separation of non-miscible liquids
- B01D17/0208—Separation of non-miscible liquids by sedimentation
- B01D17/0214—Separation of non-miscible liquids by sedimentation with removal of one of the phases
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
- B01D17/02—Separation of non-miscible liquids
- B01D17/04—Breaking emulsions
- B01D17/047—Breaking emulsions with separation aids
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
- B01D17/08—Thickening liquid suspensions by filtration
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
- B01D17/08—Thickening liquid suspensions by filtration
- B01D17/085—Thickening liquid suspensions by filtration with membranes
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G31/00—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for
- C10G31/08—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by treating with water
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/40—Separation associated with re-injection of separated 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
- 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
Abstract
From the mixture containing the water hydrocarbon emulsion surfactant existence, be separated the method and system of hydrocarbon phase, comprise and regulate mixture salinity that the hydrocarbon in emulsion and water are released into hydrocarbon phase and salt aqueous solution phase respectively; Hydrocarbon phase is at least partially separated with salt aqueous solution phase, and wherein salt aqueous solution phase is at least partially recovered for further use.
Description
Technical field
The present invention relates to the recovery of hydrocarbon.Especially but unique, the present invention relates to the method and apparatus of improvement, it is for separating of the mixture comprising hydrocarbon aqueous emulsion.
Background technology
The large class organic compound that hydrocarbon is made up of hydrogen and carbon.Such as, crude oil, natural gas, kerogen (kerogen), pitch, pyrobitumen, asphaltene are all the mixtures of different hydrocarbon.Although hydrocarbon is generally defined as the molecule formed primarily of carbon and hydrogen atom, they also can comprise other elements, such as but not limited to, halogen, metallic element, nitrogen, oxygen and/or sulphur.
That hydrocarbon is normally reclaimed from each stratum by various method or production.The technology that " reclaims for the first time " refers to that the energy utilizing hydrocarbon self to be formed reclaims hydrocarbon from stratum.But first recovery only can reclaim the sub-fraction of oil reservoir oil in place.Therefore, develop secondary technology, as water flood, and numerous three technology (being commonly called the technology of " strengthening oil reclaims " (EOR)), wherein the main purpose of these technology is hydrocarbon of the recyclable known additional quantity be present in oil reservoir.
Modal a kind of secondary technology is water flood.But even if through typical water flood, oil reservoir also can retain the quite most hydrocarbon of oil in place.As everyone knows, after typical water flood, the major part in oil reservoir retains the form that hydrocarbon is bead or droplet, and it is trapped in reservoir pore space.The droplet generation deformation that high normal interface tension force between oil reservoir water and hydrocarbon stops these to be separated carrys out the narrow shrinking structure by duct.
Be called as in three technology of " oil that chemicals strengthens reclaims " (cEOR) at some, surfactant is added into the aqueous solution for injecting to reduce the interfacial tension between water and hydrocarbon, thus allows the little droplet deformation of hydrocarbon and along with the water flow injected.It has been generally acknowledged that, for effective recovery, the interfacial tension between oil and water must be down to from normal oil reservoir interfacial tension (it is similar to about 20 dynes per centimeter) and be less than 0.1 dynes per centimeter.
A lot of patent describes the cEOR using chemical surfactant and polymer, and wherein comprising U.S. Patent number is 3,508, and 611,3,823,777,3,981,361,4,058,467,4,203,491,4,232,738,4,362,212,4,411,816,4,458,755,4,493,371,4,501,675,4,502,541,4,799,547,5,031,698,5,068,043,6,022,834,6,613,720,6, the patent of 989,355 and Canadian Patent number are 1,169, the patent of 759.Basically, mentioned by the SPE paper number 7053 delivered about the seminar that petroleum recovery is improved one's methods in April, 1978, successfully reclaim oil residues by chemical waterflooding and must observe two principles: the interfacial tension between (1) chemicals storehouse (chemical bank) and oil residues and between chemicals storehouse and drive fluid is very low; (2) Loss of Surfactants be retained on a small quantity enters reservoir rocks.
During cEOR, the low interfacial tension in chemicals storehouse causes the formation of microemulsion usually, and (U.S. Patent number see people such as such as Gogarty is 3,254, the patent of 714, be disclosed in June, 1966, and the U.S. Patent number of Healy is 3,981, the patent of 361, is disclosed on September 21st, 1976).Microemulsion, it can be inject or formed on hydrocarbon stratum, is the micellar mix of oil, water and surfactant, usually combines with cosurfactant, cosolvent or other chemical substances.There is science dispute in the precise structure about microemulsion; In this manual, term " microemulsion " refers to the thermodynamically stable emulsion of broad sense.
Strengthen hydrocarbon reclaim in, the preparation of injection mixture usually based on the identification of state variable, " mesophase spherule " (or Winsor III-type) microemulsion that these state variables cause so-called and excessive hydrocarbon and excessive water all to balance." optimum salinity " is considered to usually can oil in given mixture and produce minimum interfacial tension between water and then cause the concrete salinity of middle-phase mes liquid.
In the oil reservoir using cEOR water filling, the liquid reclaimed from producing well is mixture (emulsion) form normally, comprises hydrocarbon, water and surfactant.These mixtures due to the interfacial tension reduced the relatively stable and microemulsion typically comprising the moisture and hydrocarbon of component as a kind of component.
Petroleum industry is being sought mixture that cost-effective method produced by surfactant water filling these (particularly their microemulsion component) always and is being carried out breakdown of emulsion component, be used for reclaiming the valuable chemicals be present in described mixture, with again in cEOR.
Such as, describe a kind of method in GB2146040, the method is used for carrying out breakdown of emulsion to containing microemulsion as a kind of oil-water-surface active agent emulsions of component component.The method by temperature and salinity are carefully controlled separating oil, salt solution and surfactant in certain exercisable scope, thus produces the oil and the injectable salt solution/surfactant phase that meet pipeline quality.
US2009/0281003 relates to a kind of method, and in the method, the chemicals in cEOR stream or have in aqueous phase, or has to, in organic phase, be then concentrated and be injected again in oil bearing bed.
But, still need sustainable and cost effective method and system, for separate hydrocarbons from cEOR mixture.Accordingly, the present invention seek solve technical problem for provide a kind of than prior art more sustainable and/or have more cost-benefit hydrocarbon be separated method and system.
Summary of the invention
From first aspect, broad sense of the present invention be a kind of method isolating hydrocarbon phase from the input mixture comprising the water hydrocarbon emulsion that there is surfactant, the method comprises: regulate mixture salinity, discharges hydrocarbon respectively and water becomes hydrocarbon phase and salt aqueous solution phase from emulsion; And will be separated with salt aqueous solution phase by hydrocarbon phase at least partially, wherein salt aqueous solution phase is recovered (or being retained) at least partially, for further purposes.
Because input mixture comprises hydrocarbon, water and surfactant, therefore it typically comprises---at least as a kind of component component---and microemulsion.Hydrocarbon in input mixture and the interfacial tension between water can be such as lower than 1 dynes per centimeter.
Input mixture can be preferably the mixture produced by cEOR, and therefore can comprise cosurfactant further, cosolvent or other chemicals, as known in the art.In addition, cEOR mixture has the salinity consistent with the operation requirements that hydrocarbon reclaims.Be a main target owing to reducing interfacial tension, some cEOR mixtures may reach or close to " optimal salinity ".Therefore, input mixture advantageously can have the salinity identical or approximate with its " optimal salinity ".Such as, but the salinity of input mixture can change, based on the operation requirements that hydrocarbon reclaims, or as the result of carrying out diluting, concentrating or process before the inventive method.
Known salinity has impact to interfacial tension in the mixture of water-hydrocarbon-surfactant, is therefore the state variable being used for controlling, particularly reducing the emulsification degree in this mixture in the present invention, its objective is and isolate hydrocarbon phase.Other state variables, as temperature and pressure, advantageously can keep in fact constant.
Method of the present invention, can especially effectively and sustainably utilize salinity as state variable, for particularly in microemulsion (as obtained from cEOR those) separate hydrocarbons from emulsion.Particularly, reclaiming this step of salt aqueous solution phase at least partially, method of the present invention by comprising, can again utilize salt and/or water to regulate the salinity of input mixture.Therefore, in the methods of the invention, salt and/or water need not be lost in hydrocarbon separation process.When large-scale operation, this is a significant advantage, because obtain the cost of water, especially salt in this situation, and the cost of transportation be associated, may be important commercial factors.
Therefore, in a preferred embodiment of the invention, described method can comprise reuses salt aqueous solution phase at least partially, such as, is contained in salt wherein and/or water, to regulate the salinity of this mixture as mentioned above.
In order to as much as possible reuse salt aqueous solution phase, method of the present invention can continued operation, also can by incessantly a collection of input mixture (continuously) method process of the present invention.Most advantageously, the method can be carried out in the mode of Continuous Flow.Or the method can be implemented in multiple batches.Compared with the batch operation of the method operates with Continuous Flow, usual efficiency is lower, but can be particularly advantageous when the method is intermittent use, or when each step of the method carries out being particularly advantageous at diverse geographic location, this be the option in the scope of the invention.
Hydrocarbon and water are discharged into hydrocarbon phase and salt aqueous solution phase and realize by the increase of salinity or reduce from emulsion.Regulate the salinity of input mixture can comprise the salinity increasing or reduce this mixture thus.The increase of salinity by salt being added to input mixture and/or realizing except anhydrating from input mixture, and the minimizing of salinity by from input mixture except desalting and/or adding water to realize in input mixture.
Selecting to increase or reduce the salinity of input mixture at input mixture, the input mixture such as got from cEOR, is be in be positioned at or close to being obvious especially when " optimum salinity ".In such mixture, no matter a relatively little salinity adjustment, be increase or reduce, hydrocarbon and water can be caused to discharge from the emulsion of input mixture, i.e. breakdown of emulsion.
Exceed in the mixture of " optimum salinity " in salinity, increasing salinity may be more economical, and in the mixture of salinity lower than " optimum salinity ", reducing salinity may be more economical.But, select whether will by increasing or reduce salinity and adjusting the salinity of input mixture time, operational consideration performance leading role.Therefore preferred in the present invention, regulated the salinity of input mixture by the salinity increasing input mixture, because this provide the special chance again utilizing the salt aqueous solution phase of recovery, as described hereinafter.
For effectively reusing salt aqueous solution phase especially, the method can comprise the desalination of salt aqueous solution phase further to provide first logistics with relative high salinity, with second logistics with relative Low-salinity.Desalination can be carried out, such as, by nanofiltration or inverse osmosis in any suitable desalination place or unit.
First high salinity logistics can advantageously be used (or being recycled) to increase the salinity of this mixture, that is, help breakdown of emulsion as mentioned above.In order to meet this function, high salinity logistics must have the salinity of the salinity higher than input mixture.Therefore, high salinity logistics advantageously should have the salinity higher than input mixture salinity.
Surfactant in input mixture had generally both been distributed in water and had also been distributed in hydrocarbon.After regulating the salinity of mixture, surfactant (with any cosolvent that may exist) to be transferred in hydrocarbon phase in (if salinity increase) or aqueous phase (if salinity reduction).But this transfer is incomplete, therefore, in the hydrocarbon phase be separated from this mixture all the time remaining at least some surfactant (and cosolvent, if present), and usually along with the salt of remarkable concentration.The concentration of this surfactant for hydrocarbon phase further processing or to use may be less desirable, particularly when the salinity increase of input mixture ordered about a large amount of surfactants enter hydrocarbon phase when.In addition, remaining in the object of the surfactant in hydrocarbon phase for cEOR is a kind of loss, therefore becomes the cost that of cEOR process is extra.In order to reduce Loss of Surfactants and purifying hydrocarbon phase, method of the present invention, advantageously can comprise washing hydrocarbon phase further and therefrom reclaiming surfactant and optional salt.
Very easily, can reusing and the Low-salinity logistics that desalting processing obtains is carried out to salt aqueous solution phase, therefrom reclaiming surfactant and optional salt for washing hydrocarbon phase.Be undesirable because hydrocarbon phase and Low-salinity logistics form stable emulsion, therefore Low-salinity logistics preferably can be carried out desalination and makes its salinity lower than the salinity of input mixture.Therefore, for taking typical cEOR input mixture into account, Low-salinity logistics can have the salinity lower than " optimum salinity ".
After washing, preferable separate hydrocarbon phase, to form the crude stream of purifying, leaves moisture surfactant returned logistics.In cEOR process, surfactant returned logistics advantageously can be refilled hydrocarbon containing formation, optionally combine with the salt in the first high salinity logistics.
Second aspect, broad sense of the present invention be the hydrocarbon piece-rate system being applicable to perform described method according to a first aspect of the present invention, this system comprises: entrance, for introduce comprise surfactant exist under the mixture of water hydrocarbon emulsion; Salinity regulation station, for regulating the salinity of this mixture; Separator, for being separated hydrocarbon phase and salt aqueous solution phase from mixture; And retracting device, for further use for reclaiming salt aqueous solution phase at least partially.
Retracting device can advantageously comprise a conduit, for circulate at least partially salt aqueous solution phase to salinity regulation station to regulate the salinity of this mixture.
In order to help hydrocarbon phase from aqueous phase separation, piece-rate system can comprise film, such as ceramic membrane.Film can as unique separator, maybe can in conjunction with phase separation container.
For effectively using salt aqueous solution phase further, this system can also comprise desalter, for salt aqueous solution phase desalination to provide first logistics with relative high salinity and second logistics with relative Low-salinity.Desalter can comprise a reverse osmosis units, or nano-filtration unit, or reverse osmosis units and be located thereon the nanofiltration of trip, ultrafiltration or Microfiltration Unit.
Preferably, this system can comprise a pipeline, for introducing the first logistics to salinity regulation station to increase the salinity of this mixture.
This system advantageously can comprise wash mill further, for washing hydrocarbon phase and reclaiming surfactant circulation logistics, also comprises conduit, for introducing the second Low-salinity logistics to wash mill.In this system, the additional advantage of surfactant circulation logistics is, it becomes a self-centered system.
The present invention also comprises the various components used further with reusing the mixture being separated self-contained water, hydrocarbon and surfactant.Therefore, from the third aspect, the invention reside in the oil recovery method that a kind of chemicals strengthens, comprise and inject the surfactant of the recovery as described in this paper any place from hydrocarbon phase to hydrocarbon containing formation.Preferably, surfactant can be combined with the salt of the recovery such as herein described by any place, such as, combine before injection.
Except as otherwise noted, term as used herein should be explained based on the definition of its standard in the art.Equally, except as otherwise noted, parameter provided herein is based on related standards measuring technique (ISO can when).
Term used herein " emulsion " only refers to the mixture of two or more immiscible liquids.
One skilled in the art will appreciate that the lower water hydrocarbon emulsion of surfactant existence can cause the formation of at least some " microemulsion " (i.e. a kind of thermodynamically stable emulsion).
Term used herein " interfacial tension " refers to the film-strength of separation two kinds of Immiscible fluids (hydrocarbon and water), measures with dyne every centimetre, measures according to ASTM D971.
Term used herein " salt " refers to all water-soluble salt.Sodium chloride is preferred salt.
Term used herein " salinity " refers to the amount of the salt dissolved in water.Here the salinity of indication can be determined according to practical salinity scale 1978 (PSS78), and its at first exploitation is used for seawater, relate to be compared at 15 DEG C, the electrical conductivity of the solution of 32.4356g/kg potassium chloride.
Term used herein " optimum salinity " is the concentration producing the salt of minimum interfacial tension in the mixture of given hydrocarbon, water and a surfactant between oil and hydrocarbon.Its measurement adopts the interfacial tension mensuration of standard to measure, or from additive method, as phase behavior method of testing, it is known to those skilled in the art.
Here term used " surfactant " or " surface reactive material " refer to any chemical substance that can reduce interfacial tension between hydrocarbon and water.
the explanation of preferred embodiment
Now, with reference to the accompanying drawings, only mode exemplarily, the present invention will be described, wherein:
Fig. 1 is the schematic diagram of the hydrocarbon piece-rate system for reclaiming separate hydrocarbons in mixture from hydrocarbon according to the first embodiment of the invention;
Fig. 2 is the schematic diagram of the hydrocarbon piece-rate system for reclaiming separate hydrocarbons in mixture from hydrocarbon according to the second embodiment of the invention;
Fig. 3 is the schematic diagram of the hydrocarbon piece-rate system for reclaiming separate hydrocarbons in mixture from hydrocarbon according to the third embodiment of the invention.
Referring to figs. 1 through 3, according to hydrocarbon piece-rate system and the hydrocarbon phase of method (or process) separately for extracting from input mixture or being separated of following three exemplary of the present invention.The mixture of input comprises the emulsion of water and hydrocarbon formation under surfactant (surface reactive material) exists.Although input mixture can for any suitable source, in practice, it is modal for reclaiming at chemicals strengthening oil the mixture obtained in (cEOR) logistics.
Comprise according to the hydrocarbon piece-rate system of three exemplary of the present invention and method: adjustment, particularly increase, the hydrocarbon in this emulsion and water are released into hydrocarbon phase and salt aqueous solution phase by the salinity of input mixture.After this, hydrocarbon phase is separated for further use at least partially, and salt aqueous solution phase is at least partially recovered for re-use.
In order to raise the efficiency to greatest extent, carry out in single system or facility in Continuous Flow mode separately according to the method in illustrative embodiments of the invention.It is to be understood, however, that each stage of the method also can carry out in batches, no matter also or on multiple different geographical position carry out in single equipment in batches.
First, with reference to Fig. 1, in first embodiment of the invention, the conventional emulsion cEOR mixture 1 comprising hydrocarbon (form with crude oil), water and surfactant comprises and is imported in hydrocarbon recovery system.
Surfactant in cEOR mixture 1 can be any known type being suitable for cEOR.Except surfactant, cEOR mixture can comprise other additive as known in the art.
CEOR mixture 1 has the palaeosalinity of an effective cEOR of energy support, provides the interfacial tension between the oil of reduction and water, such as, be approximately less than 1 dynes per centimeter at this salinity lower surface activating agent.Usually, cEOR mixture 1 is equal or close to optimum salinity.
In order to be reduced in the emulsification degree in cEOR mixture 1, namely release oil and water are to independent oil phase and aqueous phase, and mixture is directed into salinity regulation station S at first.The ability that salinity Surfactant reduces interfacial tension in cEOR mixture has very strong impact.Such as, the high salinity exceeding cEOR mixture " optimum salinity " makes microemulsion by breakdown of emulsion, thus causes the formation of oil phase (or hydrocarbon) and the aqueous phase (or water) increased.Salt contained in this mixture tends to mainly dissolve in aqueous phase, but some salt also can be present in oil phase, and simultaneously along with the increase of salinity, the surfactant increasing ratio is forced to and enters in hydrocarbon ils.
At salinity regulation station S, it such as can comprise a suitable conduit (as Figure 1-3) or container simply, and the input 11 of high salinity mixes to increase the salinity of mixture to the salinity more than cEOR mixture " optimal salinity " with cEOR mixture 1.The input 11 of high salinity has the salinity larger than cEOR mixture 1, and comprises the salt of recovery, as will be discussed later.
The ratio that the input 11 of cEOR mixture 1 and high salinity is mixed depends on a number of factors, the composition (comprising salinity) comprised as cEOR mixture 1 and the salinity of high salinity input 11.Those skilled in the art can select simply by carrying out regular visual examination to determine whether the degree of emulsification in cEOR mixture 2 reduces, thus determine that salinity necessary in mixture 2 increases.
Salinity increase EOR mixture 2, and increase oil phase and aqueous phase, be directed to (or demulsifier) container A that is separated.Phase separation container is well known in the art, and utilizes the density variation of oil phase and aqueous phase to be separated oil phase and aqueous phase.Phase separation container A, and all phase separation container mentioned herein, can take any suitable form, and can such as, Perry ' s Chemical Engineer ' s Handbook, 6
thedition, the type that 21-64 page describes and other types.
The EOR mixture 2 that salinity increases by phase separation container A is separated into oil phase 3 and aqueous phase 6.Oil phase 3 is purified to provide crude oil, and as will be described, aqueous phase 6 is recovered for further use simultaneously, is particularly re-used in salinity adjustment.
Still with reference to Fig. 1, aqueous phase 6 is directed into a desalination platform B by film M.Film M is used for from aqueous phase 6, remove any residual oil.Reader due to such as art technology can recognize, typically usually only provide purity to a certain degree in the process be separated, it uses film M as a supplement when aqueous phase 6.Film M can be any film be suitable for except dealkylation from water, such as such as ceramic membrane.Suitable ceramic membrane comprises TiO
2, ZrO
2, Al
2o
3or SiC.The pore size of a suitable ceramic membrane is suitable suitably for being less than 100nm, is preferably less than 50nm, is more preferably less than 30nm, be most preferably less than 10nm.Can use hydrophobic film, this causes effectively from aqueous phase, removing oil phase.Suitable hydrophobic film comprises the ceramic membrane of grafting, such as grafting containing ZrO
2film, and polymer film, such as, based on the film of poly-(dimethyl siloxane) (PDMS) or polyimides.
After the oil removing of the film M degree of depth, the desalination platform B that aqueous phase 6 enters, it is processed into a Low-salinity logistics 7 and a high salinity logistics 8 there.Desalination platform B can adopt conventional counter-infiltration or nanofiltration, as at " Reverse Osmosis-A Practical Guide for Industrial Users ", and W.Byrne, Tall Oaks Publishing Inc., disclosed in March 1995.
The high salinity logistics 8 produced by desalination platform B all or part ofly can be used as high salinity input 11 regulation station of adding in the cEOR mixture in salinity regulation station S.When hope only uses the logistics of part high salinity in salinity regulation station S time, such as, carry out the mesohaline excessive buildup of anti-locking system, high salinity stream 8 can be separated in salinity outlet 10.Salinity outlet 10 except desalting from system, such as, can reinject 12 for cEOR.
The water-based Low-salinity logistics 7 produced by desalination platform B is used to washing and is separated the oil phase 3 obtained from cEOR mixture 2.Still with reference to Fig. 1, the surfactant of oil phase 3 usually containing quite large concentration (this is the result because cEOR mixture salinity increases) with some salt.Therefore, Low-salinity logistics 7 mixes with oil phase 3 to form the mixture of salinity lower than " optimum salinity ", and wherein surfactant and salt are washed out from oil by Low-salinity logistics.Although there is surfactant, due to low-level salinity, mixture only shows minimum emulsification.In addition, surfactant and salt are washed in Low-salinity logistics 7 from oil phase 3, Low-salinity logistics is become aqueous tenside circulation logistics 9 and oil phase is become the crude stream after washing 5.
Surfactant circulation logistics 9 is separated in (demulsifier) container C at second-phase and is separated from crude stream 5.Crude stream 5 can be processed further by refining with as required, can be used for cEOR simultaneously reinject 12 containing the surfactant of quite large concentration and the surfactant circulation logistics 9 of salt.
It should be noted that crude stream 5 is particularly suitable for further refining, because it is desalted, save the de-salting operation in refinery.
In a word, according to hydrocarbon piece-rate system and the method for the first exemplary of the present invention, breakdown of emulsion (particularly microemulsion) can be carried out by the salinity increasing cEOR mixture and from cEOR mixture, be separated hydrocarbon phase for further, reuse or cyclic salt remaining aqueous phase in piece-rate system, and for the reflooded reusable water containing aqueous phase of cEOR and optional remaining salt.
Referring now to Fig. 2, according to the second embodiment of the invention hydrocarbon piece-rate system and method are identical with system and method according to the first embodiment of the invention, identical Reference numeral is used for identical parts, and difference is the work of the desalting steps at desalination platform B.
The desalination platform of system according to the second embodiment of the invention comprises the nano-filtration unit B1 together with reverse osmosis units B2 arranged in series.Or nano-filtration unit B1 can be ultra filtration unit or the Microfiltration Unit (not shown in Fig. 2) of one.The advantage of such arrangement is, the bivalent cation that can remove from system.Specifically, nano-filtration unit B1 removes and abandons bivalent cation.After this, reverse osmosis units B2, in salt aqueous solution phase 6, in first embodiment of the present invention desalination platform B mode, processes remaining salt and water, to form high salinity logistics 8 and Low-salinity logistics 7.
Referring now to Fig. 3, according to the third embodiment of the invention hydrocarbon piece-rate system and method are identical with system and method according to the first embodiment of the invention, identical Reference numeral is used for identical parts, difference is that film M is as phase separator, thus does not need independently phase separator.
Being separated in third embodiment of the invention occurs in film M, and it allows by aqueous phase, but does not allow to pass through hydrocarbon phase.Aqueous phase adds by film M and by high salinity input 11 increase and the breakdown of emulsion in input mixture 2 subsequently that salt can cause salinity, and namely hydrocarbon and water are released into hydrocarbon phase and aqueous phase separately from emulsion.Then, gravity principle and the technology be known in the art can be used to guide and be separated hydrocarbon phase for further process, and aqueous phase continues warp with film M to desalination platform B.
It should be noted that and use film M as a phase separator, make via except anhydrating in input mixture, instead of add salt, increase salinity.Therefore, in a change programme of third embodiment of the invention, input salt at salinity regulation station S and there is no need, be therefore omitted, this means that salt in high salinity logistics 8 can export 10 via salt and be re-used in that other are local, such as cEOR reinjects 12.
It is to be appreciated that dispensable according to some aspect of the method for the present invention first, second, and third embodiment, and without departing from the present invention, also can omit, amendment or replacement.It should be noted that and modify so that water instead of salt are recycled to salinity regulation station also within the scope of the invention to embodiment, in this case, the salinity of input mixture reduces, and---instead of increasing---comes for breakdown of emulsion.
Claims (7)
1. from the mixture containing the water hydrocarbon emulsion surfactant existence, be separated a method for hydrocarbon phase, the method comprises:
Regulate mixture salinity that the hydrocarbon in emulsion and water are released into hydrocarbon phase and salt aqueous solution phase respectively, the salinity of wherein said mixture is regulated by the salinity increasing this mixture; With
Hydrocarbon phase is at least partially separated with salt aqueous solution phase,
Wherein salt aqueous solution phase is at least partially recovered for further use, it comprises the salt aqueous solution phase reused at least partially to regulate the salinity of described mixture, by to salt aqueous solution phase desalination, to provide first logistics with relative high salinity, with second logistics with relative Low-salinity, and increase the salinity of described mixture by reusing high salinity logistics, and comprise further and reuse Low-salinity logistics to wash hydrocarbon phase for reclaiming surfactant.
2. a hydrocarbon piece-rate system, comprises:
Entrance, for introducing the mixture of the water hydrocarbon emulsion comprised under surfactant existence;
Salinity regulation station, for regulating the salinity of this mixture;
Separator, for being separated hydrocarbon phase and salt aqueous solution phase from mixture;
Retracting device, uses further for the salt aqueous solution phase reclaimed at least partially, and wherein said retracting device comprises a conduit, for the salt aqueous solution phase that circulates at least partially to salinity regulation station to regulate the salinity of this mixture; Wherein, comprise desalter further, for provide a kind of to salt aqueous solution phase desalination there is the first logistics of relative high salinity and there is the second logistics of relative Low-salinity; And
Wash mill, for washing hydrocarbon phase and reclaiming surfactant circular flow, and conduit, for guiding described second Low-salinity logistics to wash mill.
3. system according to claim 2, comprises film, and it is for by hydrocarbon phase and aqueous phase separation.
4. system according to claim 3, wherein, no matter described film, as separator, is independent or in conjunction with phase separation container.
5. system according to claim 2, wherein, described desalter comprises reverse osmosis units, nano-filtration unit or reverse osmosis units and is located thereon the nano-filtration unit of trip.
6. an oil recovery method for chemicals strengthening, comprises and injects surfactant that method as claimed in claim 1 reclaims to hydrocarbon containing formation.
7. chemicals oil recovery method according to claim 6, wherein, surfactant with merge from the salt in high salinity logistics described in claim 1.
Applications Claiming Priority (3)
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|---|---|---|---|
| EP10176226.8 | 2010-09-10 | ||
| EP10176226 | 2010-09-10 | ||
| PCT/EP2011/065658 WO2012032161A1 (en) | 2010-09-10 | 2011-09-09 | Improvements relating to hydrocarbons recovery |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN103096989A CN103096989A (en) | 2013-05-08 |
| CN103096989B true CN103096989B (en) | 2015-09-09 |
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|---|---|---|---|
| CN201180043778.5A Expired - Fee Related CN103096989B (en) | 2010-09-10 | 2011-09-09 | Relate to the improvement that hydrocarbon reclaims |
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|---|---|
| US (1) | US20140008271A1 (en) |
| EP (1) | EP2613863A1 (en) |
| CN (1) | CN103096989B (en) |
| BR (1) | BR112013004602A2 (en) |
| CA (1) | CA2812977A1 (en) |
| EA (1) | EA201390365A1 (en) |
| MX (1) | MX2013002580A (en) |
| WO (1) | WO2012032161A1 (en) |
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| US9751777B1 (en) * | 2011-04-26 | 2017-09-05 | Mansour S. Bader | Treatment of produced water from unconventional hydrocarbons exploration |
| US10441898B1 (en) * | 2014-02-08 | 2019-10-15 | Mansour S. Bader | Vertical integration of source water treatment |
| EP2882933B1 (en) * | 2012-08-09 | 2018-11-28 | Shell International Research Maatschappij B.V. | Process for producing and separating oil |
| DK2882932T3 (en) * | 2012-08-09 | 2018-06-14 | Shell Int Research | OIL PRODUCTION AND SEPARATION SYSTEM |
| CA2794072A1 (en) * | 2012-09-25 | 2014-03-25 | Shell Internationale Research Maatschappij B.V. | Method for removing fine solids from an aqueous bitumen-containing stream |
| US10508048B2 (en) | 2015-04-07 | 2019-12-17 | Conocophillips Company | Removal of oil recovery chemicals from production fluids |
| CN107429559B (en) * | 2015-04-07 | 2020-04-17 | 科诺科菲利浦公司 | Oil recovery chemicals removal from produced fluids |
| US10464831B1 (en) * | 2015-06-06 | 2019-11-05 | Mansour S. Bader | Treatment of produced water from unconventional sources of hydrocarbons |
| US10419514B2 (en) * | 2015-08-14 | 2019-09-17 | Oracle International Corporation | Discovery of federated logins |
| US20180058186A1 (en) * | 2016-08-31 | 2018-03-01 | General Electric Company | Systems and methods for coated salts |
| WO2018095881A1 (en) * | 2016-11-24 | 2018-05-31 | Shell Internationale Research Maatschappij B.V. | Process for oil recovery |
| US10953352B2 (en) | 2017-05-19 | 2021-03-23 | Baleen Process Solutions | Fluid treatment system and method of use utilizing a membrane |
| US20180333654A1 (en) * | 2017-05-19 | 2018-11-22 | Jarid Hugonin | Fluid Treatment System and Method of Use Utilizing a Membrane |
| US10703989B2 (en) * | 2017-09-29 | 2020-07-07 | Saudi Arabian Oil Company | Conserving fresh wash water usage in desalting crude oil |
| GB2575243A (en) * | 2018-06-08 | 2020-01-08 | Bp Exploration Operating Co Ltd | Computerized control system for a desalination plant |
| FR3107458A1 (en) * | 2020-02-26 | 2021-08-27 | IFP Energies Nouvelles | Device and method for separating two immiscible liquids by means of a bicontinuous phase |
| FR3110929B1 (en) * | 2020-05-29 | 2022-10-21 | Ifp Energies Now | METHOD FOR THE RECOVERY OF HYDROCARBONS FROM AN UNDERGROUND FORMATION BY INJECTION OF AN AQUEOUS SALINE SOLUTION COMPRISING A SURFACTANT |
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- 2011-09-09 EA EA201390365A patent/EA201390365A1/en unknown
- 2011-09-09 CA CA2812977A patent/CA2812977A1/en active Pending
- 2011-09-09 BR BR112013004602A patent/BR112013004602A2/en not_active IP Right Cessation
- 2011-09-09 CN CN201180043778.5A patent/CN103096989B/en not_active Expired - Fee Related
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Also Published As
| Publication number | Publication date |
|---|---|
| US20140008271A1 (en) | 2014-01-09 |
| BR112013004602A2 (en) | 2016-07-05 |
| EP2613863A1 (en) | 2013-07-17 |
| EA201390365A1 (en) | 2013-07-30 |
| WO2012032161A1 (en) | 2012-03-15 |
| MX2013002580A (en) | 2013-04-03 |
| CN103096989A (en) | 2013-05-08 |
| CA2812977A1 (en) | 2012-03-15 |
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