CN103889530A

CN103889530A - Treatment of oil and oil-containing formulations

Info

Publication number: CN103889530A
Application number: CN201280051986.4A
Authority: CN
Inventors: 菲利普·弗莱彻; 杰弗里·福赛斯; 科里·杰斯卡
Original assignee: Oilflow Solutions Holdings Ltd
Current assignee: Oilflow Solutions Holdings Ltd
Priority date: 2011-08-24
Filing date: 2012-08-20
Publication date: 2014-06-25
Also published as: GB201403102D0; WO2013027038A1; US20140332446A1; CA2846293A1; MX2014001751A; GB201114631D0; AU2012298373A1; GB2507451A

Abstract

There is disclosed a method of separating a mixture (e.g. dispersion) of oil and water into oil- rich and water-rich phases, the method comprising the steps: (i) selecting a mixture which comprises oil recovered from a subterranean formation and a treatment formulation, wherein the treatment formulation was added to the oil in order to facilitate its recovery and/or mobility, wherein the treatment formulation has an Interfacial Tension (IFT), measured against a sample of the oil in the range 2 to 20 mN/m; (ii) directing the mixture to a separation means; and (iii) in the absence of a chemical demulsifier, heating the mixture until separation is effected at least partially under gravity. Preferably the IFT is in the range 9 to 12mN/m. The mixture of oil and water may be formed by treating oil in a subterranean formation.

Description

The processing of oil and oil-including formulation

The present invention relates to the processing of oil and oil-including formulation (oil-containing formulation).Preferred embodiment relate to formulation example as the separation of dispersion liquid, described preparation comprises the oil water mixture having reclaimed from stratum (subterranean formation).

Many oil-including formulations comprise the oil that can not reclaim by ordinary student production. art, because this oil viscosity is too high.Known by with surface active material to reduce oily apparent viscosity and to help it to flow to manage to address this problem.Known surface active material comprises emulsifying surfactant, such as described in US5641433 (Intevep), described emulsifying surfactant is provided with aqueous compositions, and is arranged to and forms the oil-in-water emulsion with the apparent viscosity lower than apparent viscosity of oil itself.Therefore, oil can more easily transport and/or reclaim.

But the oil/water/surfactant mixture being recovered, needs processed to optimize oily amount and preferably to separate the oil that contains low-level water and/or surfactant.But this has challenge.In fact, as the prepared mixture described in US5641433 can not be easily satisfactorily separated and therefore emulsion sold according to trade mark ORIMULSION (trade name), for low-level purposes, for example, as burned fuel.In other prior aries, chemical demulsifying agent can be for destroying the oil-in-water emulsion reclaiming.But adversely, this technique need to be used the other expensive chemicals of possibility in other processing step, described chemicals increases cost and the complexity of oil content separating process.

The object of the invention is to solve problem described above.

The object of this invention is to provide the means for separating of oil-in-water emulsion, reduce simultaneously and/or eliminate the effect of chemical demulsifying agent.

According to a first aspect of the invention, provide the method that the mixture (for example dispersion liquid) of oil and water is separated into rich oil phase and water-rich phase, the method comprising the steps of:

(i) select mixture and treatment agent, described mixture comprises the oil reclaiming from stratum, wherein said treatment agent is added in oil, to promote oily recovery and/or mobility, wherein said treatment agent has the interfacial tension within the scope of 2 to 20mN/m (IFT) that records of sample of the described oil of contrast;

(ii) described mixture is introduced to separator; And

(iii) in the non-existent situation of chemical demulsifying agent, heat described mixture, until realize and separating at least in part under Action of Gravity Field.

Because some oil is too sticky and can not be measured easily for IFT, thus the sample of oil with toluene the oil with 75:25: the recently dilution of toluene.Therefore, the material of the IFT of indication based on dilution.IFT can measure by the standard method described in embodiment below.

Advantageously, in the situation that not there is not any demulsifying agent, realize at least in part and separate the use and the promotion separation process that have reduced chemicals.Separation described in step (iii) be preferably performed and without any describe the demulsifying agent being added.

Except having specific IFT, in the time that described treatment agent contacts with described oil, described treatment agent can also suitably strengthen the mobility of oil in stratum.In the time that selected treatment agent contacts with oily sample, can increase ambulant treatment agent and suitably there is at least one in following characteristics (25 DEG C of measurements), wherein oil: the ratio for the treatment of agent is 70:30:

(a) dispersion liquid of oil and treatment agent is at 1s ^-1shear rate under there is the 5000cP of being less than, be preferably less than 4000cP, be most preferably less than the viscosity of 3000cP.

(b) dispersion liquid of oil and treatment agent is at range of shear rate 1s ^-1to 100s ^-1interior is pseudoplastic.

(c) dispersion liquid of oil and treatment agent is at 100s ^-1shear rate under there is the 700cP of being not more than, be preferably less than 500cP, be most preferably less than the viscosity of 400cP.

Described treatment agent preferably includes feature (a) and arrives at least two in (c), more preferably comprises whole three features.

The rheological property at the interface between oil and preparation preferably belongs to certain structure boundary.If border is not very structuring (structured), dispersion liquid is by coalescent (coalesce) and be not movably.If border is highly structural too, dispersion liquid will be unbreakable.Preferred treatment agent need to be in " the too structuring " of indication and the middle somewhere of " not bery structuring " extreme condition.Continue this theme, interface be not preferably too resilient-for example it is not can distortion under stress application instead of fracture and coalescent interface suitably.Simple viewpoint is that high interfacial structure can be equal to high interfacial viscosity and low interfacial structure can be equal to low interfacial viscosity.But the rheological property of fluid is complicated and multidimensional, therefore represents fully that hardness, structure and the elasticity at interface is difficult, reason is that these performances are relevant to the tissue of interface molecule, and the tissue of molecule is minimum and is difficult to processing.Modern rheology method shows, the structure at interface can utilize its non newtonian aspect ratio of research to study as: interfacial viscosity, the rheology methodology of shearing dependence, viscosity modulus, elastic modelling quantity, complex viscosity and phase angle etc.

Described separator comprises the first container suitably, and wherein said mixture is transported in described the first container.The method preferably includes heating and is transported to the mixture in the first container wherein at described mixture.The method preferably includes the mixture in the first container is heated to at least 40 DEG C suitably, preferably the step of the temperature of at least 50 DEG C.Mixture can be heated to lower than 90 DEG C.Preferably, mixture is heated in the scope of 50 DEG C to 90 DEG C.Described mixture can be heated (for example therefore its in the scope of 50 DEG C to 90 DEG C) at least 1 hour as described, and at least 12 hours, at least 24 hours or at least 36 hours; It can be heated as the aforementioned and is less than 90 hours or is less than 72 hours.

Between the described period of heating, mixture suitably separates under Action of Gravity Field, makes two be defined-lower floors of layer of material and comprises oily upper strata, and lower floor comprises water, water-soluble material and solid (if being present in mixture) such as sand.Oil reservoir can wet, because it comprises some water, but preferably it comprises the water that is less than 20wt% or is less than 10wt%.Be defined as before separating in step (iii) wt% of water in mixture and be preferably at least 2 divided by the ratio of the wt% of water in after separating upper strata, more preferably at least 3.This is than being less than 50.Lower floor can comprise the water of at least 70wt%, 80wt% or 90wt%.Lower floor can comprise the water that is less than 99wt%.The surplus of lower floor can for example, by one or more additives that contain in the described treatment agent adding (being the IFT that regulates the water of described treatment agent) and/or sand or other solids formation.

Described the first container preferably includes vent device, suitably in upper end, for removing from container gas.Described the first container preferably includes the first outlet, suitably in upper end, removes fluid for the top part from container, for example, for removing fluid from described upper strata.Therefore, the method comprises that the upper strata of the fluid from the first container removes the fluid step of (for example it comprises a large amount of oil) suitably.

Described the first container preferably includes the second outlet, suitably in lower end or approach lower end, to remove fluid from described lower floor.Therefore, the method comprises that the lower floor from the first container removes the step of fluid suitably.Preferably, the fluid of removing from described lower floor is recycled; Preferably described method comprises described fluid (it comprises active material as described below suitably) is contacted with other oil, for example, in stratum, to promote its recovery and/or mobility.The method can comprise the fluid of removing from described lower floor is transported in treatment agent container, and this container is arranged to and treatment agent is transported to wherein treatment agent contacts oily position, for example, in stratum.The method can comprise to be introduced one or more additives (for example as described below other active material) in the fluid in treatment agent container, make fluid wherein have predetermined composition and/or therefore in described preparation the concentration of active material in predetermined scope.

Described the first container can comprise for the outlet from wherein removing for example sand of solid.Therefore, described method preferably includes the step of isolating solid material from the fluid of the first container.

As preferably, in the time that described the first container comprises the first outlet, described the first outlet can be connected to second container and the method and can comprise from the top part of the first container and take out fluid and be transported to described second container.In the method, the water in fluid is separated in the oil in the fluid from second container preferably.Preferably, do not have chemical demulsifying agent (preferably without any the demulsifying agent of describing) to be added to second container.Separation in described second container preferably includes the fluid in second container is heated to at least 40 DEG C suitably, preferably the step of the temperature of at least 50 DEG C.Fluid can be heated to lower than 90 DEG C.Preferably, fluid is heated in the scope of 50 DEG C to 90 DEG C.Described fluid can be heated (for example therefore its in the scope of 50 DEG C to 90 DEG C) at least 1 hour as described, and at least 12 hours, at least 24 hours or at least 36 hours; It can be heated as the aforementioned and is less than 96 hours or is less than 72 hours.

Described second container can be arranged to fluid from it portion part be transported to other separator, this other separator can comprise traditional electrolytic cell (battery).

Described treatment agent can have interfacial tension (without any oil) at 25 DEG C, preferably 35 to 66mN/m, more preferably in 40 to 65mN/m scope.

Described IFT can be 6mN/m at least, 7mN/m at least suitably, preferably 8mN/m at least, more preferably 9mN/m at least.IFT can be less than 18mN/m, is less than 16mN/m suitably, is preferably less than 14mN/m, is more preferably less than 12mN/m, is less than 10mN/m especially.Preferably, IFT 8 to 14mN/m, especially in 9 to 12mN/m scope.

Described treatment agent comprises water and active material suitably, and wherein suitable described active material affects treatment agent with respect to oily IFT and/or by water modification, and therefore it has IFT as described herein.

Described treatment agent is suitably moisture.It comprises at least 80wt%, preferably at least 90wt%, more preferably at least 95wt%, the water of 98wt% at least especially suitably.It can comprise 99.5wt% or water still less.

Described treatment agent comprises at least 0.1wt%, preferably at least 0.3wt%, the described active material of 0.4wt% at least more preferably suitably.It can comprise the described active material that is less than 1wt%, is preferably less than 0.8wt%.

Described treatment agent comprises the water of 95wt% to 99wt% suitably, and the described active material of 0.1wt% to 1wt% and other additives of 0wt% to 3wt%, such as biocide or corrosion inhibitor.The amount of other additives can be less than 2.5wt%, is less than 2.0wt% suitably, is preferably less than 1wt%.Preferably, described treatment agent comprises water, the described active material of 0.1wt% to 1wt% and other additives of 0wt% to 1wt% of 98wt% to 99.9wt%.

Described treatment agent comprises suitably and is less than 0.01wt%, the more preferably polyethylene glycol of 0wt% p-(1,1,3,3 ,-tetramethyl butyl)-phenyl ether (for example TRITON X-100 (trade mark)).Described treatment agent comprises suitably and is less than 0.01wt%, more preferably 0wt% comprise (CH ₂cH ₂o-) _nthe polymer of repetitive.Described treatment agent comprises suitably and is less than 0.01wt%, the more preferably anionic surfactant of 0wt%.Described treatment agent comprises suitably and is less than 0.01wt%, the more preferably cationic surface active agent of 0wt%.Described treatment agent comprises suitably and is less than 0.01wt%, the more preferably zwitterionic surfactant of 0wt%.Described treatment agent comprises suitably and is less than 0.01wt%, the more preferably nonionic surface active agent of 0wt%.Described treatment agent comprises suitably and is less than 0.01wt%, the more preferably material of the amino-contained of 0wt% group.Described treatment agent comprises suitably and is less than 0.01wt%, the more preferably material containing quaternary ammonium group of 0wt%.Described treatment agent comprises suitably and is less than 0.01wt%, the more preferably material containing carboxylic acid (COOH) group of 0wt%.

The concentration that used in the method and at 25 DEG C, described active material preferably all dissolves in treatment agent.Described active material is preferably dissolved at least 1wt% in the deionized water of 25 DEG C.

Described active material can be to make: in water, it is self-assembled into the pseudo-micella of the hydrodynamic radius having in nanometer range, and these are different from macroscopical micella that conventional surfactant forms.

Preferably nonionic of described active material.

Described active material is preferably so that 1wt% aqueous solution does not have detectable cloud point.This forms contrast with the surfactant for example conventionally within the scope of 0 DEG C to 100 DEG C with cloud point.

Described active material can have and is less than 200,000, is less than suitably 150,000, is preferably less than 100,000, is more preferably less than 50,000 weight average molecular weight (Mw).Mw can be at least 5,000, preferably at least 10,000.Mw can be in 5,000 to 25,000 scope, more preferably in 10,000 to 25,000 scope.

Weight average molecular weight can be measured by light scattering, low-angle neutron scattering X-ray scattering or sinking speed.The viscosity of the aqueous solution of the polymeric material of specifying can be used Brookfield viscometer to pass through Japanese Standards Association (JSA) JIS K6726 and assess.Selectively, viscosity can be measured by other standards method.For example, can use any laboratory rotation viscometer such as Anton Paar MCR300.

The viscosity of the 4wt% aqueous solution of active material can be 2.0cP at least at 20 DEG C, preferably 2.5cP at least.Viscosity can be less than 6cP, is preferably less than 5cP, is more preferably less than 4cP.Viscosity is preferably in 2 to 4cP scope.

Described active material can comprise repetitive, and this repetitive comprises hydrophilic functional group.Described hydrophilic functional groups You selection of land Bao Kuo – O-part, and Geng You selection of land Bao Kuo – OH part.

Described active material can comprise repetitive, and this repetitive comprises relative hydrophobic functional groups.This group can be formula R ¹cO-, wherein R ¹the alkyl that representative optionally replaces, the C for example optionally replacing _1-10, preferably C _1-5alkyl.Described R ¹cO-can be acetate part.

Described active material preferably includes hydrocarbon main chain, preferably saturated, preferably aliphatic hydrocarbon main chain.

Described active material is random copolymer (different from block copolymer) preferably.

Described active material can comprise plural different repetitive.Preferably it comprises and is no more than two dissimilar repetitives.

In described active material, comprise hydrophilic functional group repetitive % by mole divided by comprise hydrophobic functional groups repetitive % by mole can be in 1.5 to 19 scope, preferably in 2 to 15 scope, more preferably in 4 to 12 scope.

When described separator comprises while comprising as described the upper and lower, described top oil reservoir comprises suitably and is less than 0.3wt%, is less than 0.2wt%, is less than 0.1wt%, is less than 0.05wt% or is less than the described active material of 0.01wt%.In lower floor, the wt% of active material can be at least 5 divided by the ratio of the wt% of active material in upper strata, preferably at least 7, more preferably at least 10.

In the first embodiment, described active material is not that the polyvinyl alcohol of the hydrolysis that is optionally cross-linked and/or its preferably do not comprise that vinyl alcohol repetitive and/or its do not comprise the polymeric material containing from its main polymer chain side Gua – O-part, and wherein said polymeric material is optionally cross-linked.But in the second embodiment, described active material can comprise polymeric material.This polymeric material comprises at least 50 % by mole suitably, preferably at least 60 % by mole, and more preferably at least 70 % by mole, the vinyl alcohol repetitive of at least 80 % by mole especially.It can comprise and is less than 99 % by mole, is less than suitably 95 % by mole, is preferably less than the vinyl alcohol repetitive of 91 % by mole.Described polymeric material comprises 60 % by mole to 99 % by mole suitably, preferably 80 % by mole to 95 % by mole, and more preferably 85 % by mole to 95 % by mole, the vinyl alcohol repetitive of 80 % by mole to 91 % by mole especially.

Described polymeric material preferably includes vinylacetate (vinylacetate) repetitive.It comprises at least 2 % by mole, preferably at least 5 % by mole, and more preferably at least 7 % by mole, the vinylacetate repetitive of at least 9 % by mole especially.It can comprise 30 % by mole or still less, or 20 % by mole or vinylacetate repetitive still less.Described polymeric material preferably includes the vinylacetate repetitive of 9 % by mole to 20 % by mole.

Described polymeric material is not preferably cross-linked.

Suitably, the vinyl alcohol repetitive in described polymeric material and vinylacetate repetitive % by mole sum be at least 80 % by mole, preferably at least 90 % by mole, more preferably at least 95 % by mole, at least 99 % by mole especially.

Described polymeric material preferably includes 70-95 % by mole, and more preferably 80 % by mole to 95 % by mole, the polyvinyl alcohol of the hydrolysis of 85 to 91 % by mole especially.

Collected described mixture in step (i), comprises suitably and is greater than 5wt%, is preferably more than 10wt%, is more preferably greater than 20wt%, is greater than especially the oil of 30wt%.Collected material can comprise the described active material that is less than 1wt% or is even less than 0.75wt%.Mixture can comprise and be greater than 30wt%, is greater than 40wt% or is greater than the water of 50wt%.

The method of first aspect can comprise step (a) before in step (i), and step (a) comprises processes oil to define selected mixture in the step (i) of the method.Step (a) can comprise makes pending oil contact with described treatment agent.

Preferably crude oil of described oil, term " crude oil " comprises the tar (heavy crude oil) and the pitch that from Tar sands, obtain in this manual.Oil can have and is less than 30 °, is less than suitably 25 °, is preferably less than the api gravity index of 20 °.In some cases, api gravity index can be less than 15 °.

Described treatment agent can be first on ground or approach ground place and contact with oil, for example, to promote oily transport in pipeline.Preferably, when oil is when underground, first described treatment agent contacts with oil.Preferably, described treatment agent is introduced into stratum.Described treatment agent is arranged to suitably to oily or relevant with the described stratum oil in described stratum and contacts.

Described treatment agent can be the temperature of environment temperature at least immediately before being incorporated in stratum.Preferably, before described introducing, this temperature exceedes environment temperature immediately.It can exceed at least 5 DEG C of environment temperatures, preferably at least 10 DEG C.

Described treatment agent is at 25 DEG C and 100s ^-1there is suitably the 0.98cP of being greater than, be greater than suitably 1cP, be preferably more than 1.2cP, be greater than especially the viscosity of 1.5cP.Described treatment agent preferably has the 10cP of being not more than under described condition, preferably 5cP or less, more preferably 2cP or less viscosity.

The water that is used in treatment agent can derive from any source easily.It can be the water in drinking water, surface water, seawater, water-bearing layer, the water that deionization produces and the water filtering from any mistake in aforementioned source.Preferably salt solution of described water, for example seawater or the salt solution such as seawater from salt solution.The amount of water as referred to herein refers to including its component suitably for example such as the water the naturally occurring component being present in seawater.Water can comprise up to the dissolving salt of 6wt% but comprise suitably and be less than 4wt%, 2wt% or 1wt% or naturally occurring dissolving salt in water still less.

In an embodiment (A), treatment agent can be transported to underground in step (a).This can comprise the oil in stratum is contacted with described treatment agent at the upstream position of producing well.Treatment agent can be introduced in stratum via Injection Well.Described Injection Well can be selected from peupendicular hole, inclined shaft or horizontal well.In certain embodiments, treatment agent can be introduced into multiple, in three or more Injection Wells, substantially introduces suitably suitably simultaneously.Preferably, in embodiment (A), the oil in described stratum makes oil move at first direction by the initial contact of described treatment agent, and the oil being wherein touched suitably did not move up in described first party before described initial contact.Preferably, the oily initial contact in described stratum increases the oily movement velocity being touched.For example, oil can be limited and therefore substantially fix (except oily molecular motion) before contact.After contact, oil can be caused mobile and therefore its speed will increase.Suitably, after contact, oily relative treatment agent is advanced with the speed for the treatment of agent together substantially.In some cases, gravity can work to oil, to be shifted to producing well, in this case, under the effect of the power that oil applies at gravity with by described treatment agent, can shift to producing well.In some embodiments, substantially only have and cause that oil shifts to the power of producing well and can provide by described treatment agent.Preferably, treatment agent is arranged (for example the pressure by being applied to it is to be introduced in stratum) and becomes to carry oil towards producing well.

After some oil have been removed by alternative method, the method for embodiment (A) can be used.The method can comprise comprise as described by step of the oil in described stratum and the contact of described treatment agent with relate to another step that stratum is contacted with different preparations.After the contact of different preparation, may there is another step, this step comprises as described the oil in described stratum is contacted with described treatment agent.

In embodiment (B), step (a) can comprise pit shaft pump performance or the efficiency that raising is relevant with pit shaft (wellbore) and/or increase the productivity ratio from the reservoir fluid in reservoir, wherein borehole pump is arranged to the wellbore fluids in pit shaft is pumped into ground, and described method comprises step:

(I) selection comprises the pit shaft of relevant borehole pump, and

(II) reservoir fluid of the entrance upstream of borehole pump is contacted with described treatment agent.

In step (II), first described reservoir fluid preferably contacts with the described treatment agent in described pit shaft.

In described embodiment (B), before contacting with described reservoir fluid, described treatment agent is defined within on the surface on ground wherein at described pit shaft suitably.It can be accommodated in container.In step (II), preferably make described treatment agent move from separating primary importance with the entrance of borehole pump, towards the second place being defined by the entrance of borehole pump.In the time moving to the described second place, described treatment agent is preferably arranged to the fluid flowing path that (preferably, in the annulus of pit shaft) extends in pit shaft and moves.Preferably, described fluid flowing path extends between the first area of pit shaft and the second area of pit shaft, the upper end of the first area adjacent well bore of described pit shaft, the second area of described pit shaft suitably below first area, preferably or the described porch of contiguous described pump.Preferably the whole of described fluid flowing path extend in pit shaft substantially.Described fluid flowing path extends at least 10m, preferably 30m at least.Preferably, in step (II), power projects on treatment agent so that treatment agent moves between described primary importance and the second place.Described power can provide by pump installation at least partly.Preferably, the main amount of described power is provided by gravity.In a preferred embodiment, treatment agent is introduced in described pit shaft and allows to fall under Action of Gravity Field, thereby moves to borehole pump.In this case, suitably, do not have pump can for the treatment agent in pick-up well cylinder flow.

In an embodiment of embodiment (B), in step (II), described treatment agent can be first contacts with the reservoir fluid in the annulus of pit shaft.Processing fluid preparation can be allowed under Action of Gravity Field, fall and move to the entrance of borehole pump after first contacting.Preferably, first treatment agent at least contacts with reservoir fluid the position of 5m at the height of the entrance that exceedes borehole pump.If comprising, pit shaft exceedes a pump, mentioned pump minimum that pump suitably.Described borehole pump can be any type.Preferably, described borehole pump is selected from protrusive cavity pump (PCP) (also referred to as eccentrie helical totorpump), beam pump (also referred to as insert pump, step-by-step movement beam type pump and drawing-in type insert pump) and for example electric submersible pump (ESP) of centrifugal pump.

In embodiment (C), first described treatment agent can contact oil at the production face on stratum or its downstream.This can be suitable for processing and be arranged to the oil mobile along fluid flowing path.Described fluid flowing path preferably defines by plumbing installation.Described plumbing installation preferably includes the first pipe section (for example pipeline), and the first pipe section is disposed in the downstream of process units, preferably on ground level.Described fluid flowing path (for example described plumbing installation) can extend between first and second point, and described first is point away from oily production, and described second point is the point of the production of more close oil, for example or the point of contiguous oily production.Described first can on ground and can be for example well head or refinery; Described second point is the production face of layer closely.It can or contiguous production face.Described fluid flowing path can partly define by the second pipe part extending up to from below ground on ground.Described second pipe part can be upspout.Described second pipe part contains oil after contacting with described treatment agent.Transport stream and be preferably defined, this transports stream and is arranged to described fluid flowing path and communicates, and wherein said treatment agent transports in the described oil that stream is added to described fluid flowing path via described.The described stream that transports preferably communicates with the described fluid flowing path in the downstream of the production face on production face on stratum or stratum.Described transport the flow velocity (in the weighing scale of unit interval) for the treatment of agent in stream with the ratio of flow velocity (with identical unit) of oil in described fluid flowing path in 0.1 to 2.5 scope, preferably in 0.2 to 1 scope, more preferably in 0.4 to 0.8 scope, especially in 0.6 to 0.7 scope.

In embodiment (D), step (a) can comprise the method that increases the production that carrys out the hydrocarbon in the reservoir that penetrates of free pit shaft, and described pit shaft comprises relevant Manual lifting device, and the method comprises:

(X) pipeline with outlet is inserted in pit shaft;

(Y) when pipeline is during by shift-in pit shaft, treatment agent is incorporated in pit shaft by the outlet of pipeline, described treatment agent is arranged to make hydrocarbon to move up.

Pipeline can be inserted into pit shaft via relevant producing well.In the time that pipeline leaves producing well by shift-in pit shaft, treatment agent is introduced into pit shaft via the outlet of pipeline.When pipeline is during by shift-in pit shaft, the treatment agent of introducing can make for example heavy oil of hydrocarbon move up, and under condition in the non-existent pit shaft of described preparation, described hydrocarbon is substantially irremovable.

Insert during pit shaft at it, the outlet of pipeline can be moved at least 25m, 50m, 100m, 200m, 300m or the distance of 400m at least.The length of the pipeline therefore, starting from ground can have above-mentioned value.Preferably, when described pipeline is moved at least 25m, 50m, 100m, 200m, 300m or at least when the distance of 400m, described treatment agent is injected continuously from described pipeline along the pit shaft extending laterally.Preferably, in the method, in the time exporting through Manual lifting device and enter the pit shaft extending laterally, treatment agent flows out from the outlet of pipeline.Preferably, in the time upwards measuring from Manual lifting device, when outlet is positioned as from Manual lifting device at a distance of 10m at least or at least when the distance of 20m, treatment agent flows out from the outlet of pipeline.Preferably, in the time that outlet is positioned as with the top of producing well at a distance of the distance of 10m or 5m, treatment agent flows out from the outlet of pipeline.Preferably, basic under whole paths of pipeline to during producing well, treatment agent flows out from the outlet of pipeline.After inserting, the outlet of pipeline and/or all pipeline are preferably fixed.When in above-mentioned fixed position, treatment agent is suitably introduced in pit shaft.Preferably, when Manual lifting device just operated with from pit shaft when the dealkylation, treatment agent is introduced into pit shaft via the outlet of pipeline.Preferably, in the time that Manual lifting device is just operated, treatment agent is continuously introduced pit shaft.

Arrive behind fixed position, treatment agent can be introduced in pit shaft within the period of at least 10 days, at least 50 days, at least 100 days, at least 1 year or at least 5 years.

According to a second aspect of the invention, provide the first container that contains in the described method of first aspect the fluid of producing after processing, described container comprises the lower floor that comprises water and active material as described and comprises oily upper strata.Described the first container can have any feature of the first container described herein that adds necessary variation.

Provide equipment according to the third aspect, it comprises:

The first container, the fluid that it produces after being contained in and processing in the method for first aspect;

Second container, its downstream at described the first container and be operably connected to described the first container, for example, so that the top part from described the first container (upper strata of fluid) is transferred to described second container by fluid;

Treatment agent container, it is operably connected to described the first container, for example, so that the bottom part from described the first container (lower floor of fluid) is transferred to described treatment agent container by fluid;

Wherein said second container comprises than described treatment agent container or the high oil of described the first container concentration; And

Described the first container contains the water more than described second container.

Described equipment can comprise any feature of the equipment described herein, preparation, method and the purposes that add necessary variation.

Any feature of any aspect of any invention described herein or embodiment can combine with any feature that adds any other invention described herein of necessary variation or any aspect of embodiment.

Concrete embodiment of the present invention is described by the mode of embodiment referring now to accompanying drawing, wherein:

Fig. 1 shows with processing fluid treatment stratum and isolate subsequently the oily schematic diagram of recovery from the processing fluid with crossing; And

Fig. 2 be with process fluid treatment and subsequently with process fluid separate before and afterwards, the figure of oil viscosity to temperature.

With reference to figure 2, process fluid tank 2 and be arranged to the downward pumping processing fluid of annulus (it contains additive) along pit shaft, described in WO2008152357, to improve the pit shaft pump performance relevant with pit shaft and efficiency and/or the productivity ratio for increasing the reservoir fluid from reservoir.Send fluid pump back to surface and enter at surperficial production tank 6 at the down-hole pump of position 4, described fluid can comprise liquid hydrocarbon (oil), reservoir water, sand and/or gas.Comprise the suitable treatments fluid of additive by selection, as mentioned below, can make oil and water, salt solution and/or the sand separation of producing in tank 6, and without add any chemical demulsifying agent in production tank 6.Separation can only complete by mixture is incubated to several days in production tank 6 at 50-90 DEG C.Between soak, comprise that sand and the fluid 8 containing the water of additive drop to the bottom of tank and rich oil 10 tops that move to tank mutually.Rich oil can comprise 1 to 25wt% water mutually.But it is not contained in substantially processes any additive containing in fluid.The rich oil that comprises wet oil mutually 10 can be transported to and sell tank 12 by (for example, every several days) termly, in sale tank 12, rich oil 10 is further incubated at 50 DEG C to 90 DEG C quilts mutually, and this causes the oil 14 being dried to separate with residual water, salt solution and/or the further of sand 16.In addition, do not need chemical demulsifying agent to cause the separation in tank 12.

Fluid 8 (it comprises substantially from all additives that are transported to the fluid in tank 6) in tank 6 is recycled to be got back to tank 2 (this is possible, because fluid 8 only comprises very low-level oil and very high-caliber additive), as represented in arrow 11.In tank 2, the concentration of additive can be adjusted by adding other additive, and making the fluid in tank 2 is desirable concentration (generally including the additive of 0.5wt%).If the water in tank 8 is not suitable for recirculation described above, it can be as by represented the processing of arrow 18.Sand in fluid 8 can be removed and is processed, as represented in arrow 20.

In tank 12, after insulation, drier oil 14 can be transported to electrolytic cell 22, and the oil 14 that this is dried in electrolytic cell is further processed suitably separate with residual water, and therefore the glassware for drinking water in 24 place's oil has the water that is less than 0.5wt%.Demulsifying agent can be used in this stage.Dry oil 24 can be as represented in arrow 26 be transported to refinery.Any water 28 being removed in electrolytic cell can be as by represented processed of arrow 30.

Have been found that in the situation that not using chemical demulsifying agent oil and the interfacial tension (IFT) depending between oil and water that separates of processing fluid.Therefore the additive, being used in oil processing can be selected according to their IFT.Embodiment 1 has described IFT can how measured.

Embodiment 1-determines the conventional method of interfacial tension by Kruss sessile drop method

The method is conventionally according to Shi-Yow Lin, Li-Jen Chen, Jia-Wen Xyu and Wei-Jiunn Wangi, Langmuir1996,11,4159-41664159.The method is carried out at 25 DEG C.But, can not pass through pin because oil is too sticky, therefore before test, by oil with toluene taking oil: toluene dilutes as the ratio of 75:25.

Kruss DSA1000 surface tensiometer is used to measure the IFT between two kinds of liquid at environment temperature J-shaped pin.In the method, the drop of definite shape, from the generation of dangling of tip-tilted pin, be suspended in the optics groove that contains one other fluid, and mathematical equation is used to calculate the interfacial tension between these two kinds of fluids simultaneously.The program using is as follows:

(i) forward the inclination angle of prism (Tilt) to 0 °.

(ii) Hamilton glass syringe is filled and is no more than the fluid to be tested of 0.4ml and guarantees not have air to be trapped within syringe.

(iii) J-shaped pin be screwed on the end of syringe and syringe is advanced in the syringe fixator on syringe unit, guaranteeing to exist the end of gap and plug to be installed in syringe unit between the glass flange of syringe and the uppermost clip of syringe fixator.

(iv) enlarging function on regulon, makes pin account for about 10% of screen.

(v) be full of by the fluid that will test completely at pin lower slider optical glass groove and this groove.Rising sample stage is until pin just in time contacts the bottom of described groove.

(vi) by figure image focu.

(vii) dose mode is set to " continuous ", inputs dose rates 20 mul/min simultaneously.Syringe unit then start push to test fluid downwards by pin and drip start form and visible on screen.The desirable shape of dripping image is the image dripping of just preparing from pin drippage.But, due to the gravity of the downward effect of embedded phase, so drop tends to form spherical form, therefore concerning sticky fluid, very difficultly determine desirable shape.Preliminary research to the method shows: very large of needs obtain consistent precise results.For optimum, dripping image needs window as much as possible, therefore amplifies and may have to be adjusted.

(viii) under low close rate, develop into suitable size and then catch image dropping in.

(ix) so calculate the interfacial tension between two kinds of fluids with software.

embodiment 2-for assessment of separating oil with contain locating of residual water in selected additive and oil the general procedure of the easiness of reason fluid

Preparation to be tested is mixed with selected oil, use the oil of 70:30: preparation ratio is to produce dispersion liquid.Then dispersion liquid is incubated to 16h at 80 DEG C in glass container.After this time, analyze content by traditional BS & W technology (ASTM standard D4007-08) and whether separate with assessment." Y " in table 1 represents that separation occurs, and " N " represents that separation does not occur.

Mentioned " residual water " is the level as measured the water in the oil of being assessed by BS & W.

embodiment 3-13-test formulation

Program assessment test formulation (concentration of additive is 0.5wt%) and result described in use embodiment 1 and 2 provide in table 1.Oil 1 and 2 has respectively at 25 DEG C 37, the viscosity of 500cP and 71,000cP.Uncertainty during IFT measures is 0.1mN/m.

Table 1

Whether table 1 illustrates how interfacial tension affects and separates.The result of embodiment 6 and embodiment 11 is interesting especially.Although the preparation of the polyvinyl alcohol that comprises 20,000 molecular weight, 89% hydrolysis of embodiment 6 separates with oily, in the time that surfactant is added as in embodiment 11, the IFT of test formulation significantly increases and separation does not occur.Therefore, the existence of surfactant hinders separating of oil and aqueous mixtures.

the comparison of oil before and after embodiment 14-processes

The Anton Paar MCR301 flow graph that use is furnished with cone-plate sensor in the temperature range of 10 DEG C to 160 DEG C with 10s ^-1shear rate measure selected oil viscosity.Selected oil has at 20 DEG C 160, the viscosity of 000cP.Make 70:30 oil: preparation dispersion liquid and by mixture separating as described in Example 2.Collect a small amount of equal portions separation oil phase and remeasure viscosity according to description above.Result provides in Fig. 2, can notice that from Fig. 2 viscograph is almost consistent, shows not to be changed by processing oil.

The invention is not restricted to the details of aforementioned embodiments.The present invention extends to one or the combination of any novelty of any novelty in disclosed feature in this description (comprising any claims, summary and accompanying drawing), or extends to one or the combination of any novelty of any novelty in the step of therefore disclosed any method or technique.

Claims

1. a method that the mixture of oil and water is separated into rich oil phase and water-rich phase, described method comprises step:

(i) select mixture and treatment agent, described mixture comprises the oil reclaiming from stratum, wherein said treatment agent is added in described oil, to promote recovery and/or the mobility of described oil, wherein said treatment agent has the interfacial tension within the scope of 2 to 20mN/m (IFT) that records of sample of the described oil of contrast;

(ii) described mixture is introduced to separator; And

2. method according to claim 1, wherein in the time that selected treatment agent contacts with the sample of described oil, described treatment agent can strengthen oily mobility and have at least one in 25 DEG C of measured following characteristics, wherein oil: the ratio for the treatment of agent is 70:30:

(a) dispersion liquid of oil and treatment agent is at 1s ^-1shear rate under there is the viscosity that is less than 5000cP;

(b) dispersion liquid of oil and treatment agent is at range of shear rate 1s ^-1to 100s ^-1interior is pseudoplastic; And/or

(c) dispersion liquid of oil and treatment agent is at 100s ^-1shear rate under there is the viscosity that is not more than 700cP.

3. according to method in any one of the preceding claims wherein, wherein said separator comprises that described mixture is transported to the first container wherein, and wherein said method comprises the steps: the described mixture in described the first container being transported at described mixture to be wherein heated to the temperature at least 1 hour of at least 40 DEG C.

4. method according to claim 3, wherein between the described period of heating, described mixture separates under Action of Gravity Field, two layers of material are made to define, one deck is that lower floor and another layer of comprising water and water-soluble material are to comprise oily upper strata, and wherein said oil reservoir comprises the water and the described lower floor that are less than 20wt% and comprises at least water of 70wt%.

5. according to claim 3 or method claimed in claim 4, wherein said the first container comprises that vent device and described the first container for remove gas from described container comprises first outlet of removing fluid for the top part from described container, and described method comprises the step of removing fluid from the fluid on the upper strata of described the first container.

6. according to claim 4 or method claimed in claim 5, wherein said method comprises the step of removing fluid from the lower floor of described the first container, and the fluid wherein removed is recycled.

7. according to the method described in any one in claim 3 to 6, wherein said the first container comprises the outlet for removing solid.

8. according to the method described in any one in claim 3 to 7, wherein said the first container comprises the first outlet, described the first outlet is connected to second container, and described method comprises from the described top part of described the first container takes out fluid and taken out fluid is transported to described second container, then in described second container by the water in described fluid and oily separation in described fluid.

9. according to aforementioned method claimed in claim 8, the separation that does not wherein have chemical demulsifying agent to be added in described second container and in described second container comprises the temperature at least 40 DEG C by the described fluid heating in described second container.

10. method according to claim 8 or claim 9, wherein said second container is arranged to for fluid is transported to the other separator that comprises electrolytic cell from the top part of described second container.

11. according to method in any one of the preceding claims wherein, and wherein said treatment agent has the interfacial tension within the scope of 40 to 65mN/m in the non-existent situation of oil at 25 DEG C.

12. according to method in any one of the preceding claims wherein, and wherein said IFT is in 8 to 14mN/m scope.

13. according to method in any one of the preceding claims wherein, wherein said treatment agent comprises water and active material, wherein said active material affects described treatment agent with respect to oily IFT and/or by water modification, therefore described treatment agent has IFT as described, and wherein said treatment agent comprises at least 95wt% water.

14. methods according to claim 13, wherein said active material is that active material nonionic and/or described is to make 1wt% aqueous solution not have detectable cloud point and/or described active material to have to be less than 200,000 weight average molecular weight (Mw).

15. according to the method described in claim 13 or claim 14, and wherein said active material is not the polyvinyl alcohol of the hydrolysis that is optionally cross-linked.

16. according to the method described in any one in claim 1 to 14, and wherein said active material comprises polymeric material, and described polymeric material comprises the vinyl alcohol repetitive of at least 50 % by mole.

17. according to the method described in any one in claim 1 to 14 and 16, and wherein said polymeric material comprises vinylacetate repetitive.

18. according to method in any one of the preceding claims wherein, described method is included in step (i) step (a) before, and step (a) comprises that processing oil comprises pending oil is contacted with described treatment agent to define in the step (i) of described method selected described mixture and step (a).

19. methods according to claim 18, wherein said treatment agent has at 25 DEG C and 100s ^-1under be greater than the viscosity of 0.98cP.

20. a kind of first container, it is contained according to the fluid producing after processing in method in any one of the preceding claims wherein, and described the first container comprises lower floor and upper strata, and described lower floor comprises water and active material, described upper layer packets oil-containing.

21. equipment, it comprises:

The first container, it is contained in the fluid of processing rear generation in claim 1 to 19 in the method described in any one;

Second container, its downstream at described the first container and be operably connected to described the first container, so that the top part from described the first container is transferred to described second container by fluid;

Treatment agent container, it is operably connected to described the first container, so that the bottom part from described the first container is transferred to described treatment agent container by fluid;