CN105980656A

CN105980656A - Process for recovery of oil from an oil-bearing formation

Info

Publication number: CN105980656A
Application number: CN201480067076.4A
Authority: CN
Inventors: D·J·利塞姆; M·M·品格-阿尔马达; E·C·M·福尔摩轮; J·F·范文登; L·B·M·沃星
Original assignee: Shell Internationale Research Maatschappij BV
Current assignee: Shell Internationale Research Maatschappij BV
Priority date: 2013-10-23
Filing date: 2014-10-20
Publication date: 2016-09-28
Also published as: US20150107840A1; EA201690816A1; WO2015061194A1; EP3060746A1

Abstract

The invention discloses a process for recovery of oil from an oil-bearing formation. The present invention is directed to a process for producing oil. The mass action ratio (MAR) of divalent cations to monovalent cations of water from an oil-bearing formation is determined, and an aqueous displacement fluid having a total dissolved solids content of from 200 ppm to 5,000 ppm and a MAR of divalent cations to monovalent cations of from 70% to 130% of the MAR of divalent cations to monovalent cations of the formation water is introduced into the formation. Oil is produced from the formation after introducing the aqueous displacement fluid into the formation.

Description

By the method carrying oil formation recovery of oil

Technical field

The present invention relates to a kind of by the method carrying oil formation recovery of oil.Especially, the present invention relates to The fluid that a kind of utilization comprises polymer is by the method carrying oil formation recovery of oil.

Background technology

Owing to carrying the natural pressure of oil formation, only can gather and be present in the part oil carrying oil formation. By this " for the first time " gather gathered oil be usually in stratum oil 5-35%.Have been developed for Strengthening oil recovery method can be higher than by what load oil formation was gathered or be adopted beyond in primary recovery to increase The amount of the oil of those received.

(wherein water injects load oil formation so that oil flows and drives oil to pass through by injecting well to water drive Stratum is with from withdrawal well output) be widely used for increasing gather from stratum beyond first The secondary recovery method of the amount of the oil gathered.It is likely to be due to water fingering by the oil mass of water drive output Reducing through the oil in stratum, this is partially due to viscous between oil in injecting water and stratum Degree official post obtains water and is more easy to flowing than the oil in stratum.Formation crude stayed by the oil bypassed by water fingering At Wei, and it is generally not capable of being gathered by further water drive, this is because inject the extra of stratum Water still passes through stratum along the path of initial water.

Water-soluble polymer has been added viscosity and the fall injecting the water carrying oil formation to increase water The differences in viscosity between oil in low injection water and stratum, improve water with oil mobility ratio and by This reduces water fingering by oil.Which improve water displacement sweep efficiency in the earth formation and improve oil and adopt Receive.Waterborne polymeric mixture can be driven through stratum with class plug flow so that in stratum Oil flowing for output, wherein decrease aqueous relative to the water not having polymer and drive solution Fingering is by oil.

The water-soluble polymer of ion live-wire is used together with low salinity water, wherein " Low-salinity " Water has 15, total dissolved solidss (" the TDS ") content of 000ppm or lower, poly-to produce aqueous Polymer mixtures is for by carrying oil formation recovery of oil.The water-soluble polymer of ion live-wire and less salt Degree water is used together so that utilizing the polymer of minimum to significantly increase the viscosity of water, thus gives Fixed polymer concentration will provide higher aqueous viscosity, reduce aqueous phase salinity simultaneously.

But the viscosity of waterborne polymeric mixture may occur when introducing a mixture into load oil formation Change, this is waterborne polymeric mixture, between formation rock (mineral and clay) and formation water Ion is occurred to exchange due to the difference of ion concentration, particularly divalent cation concentration, especially It it is the result of divalent ion exchange.Ion exchange between formation water and waterborne polymeric mixture Occur when mixing, the now ion concentration of the mixture of formation water and waterborne polymeric mixture Balance, and due to waterborne polymeric mixture and the Low-salinity having than waterborne polymeric mixture The formation water mixing of water higher TDS content, may cause in the aqueous environments of polymer is total Cation and divalent cation concentration increase.Stratum is compared when the water of waterborne polymeric mixture has Ion exchange during the lower TDS content of water, between waterborne polymeric mixture and formation rock May result in bivalent cation to peel off from waterborne polymeric mixture.

If the divalent cation concentration of formation water higher than waterborne polymeric mixture bivalence sun from Sub-concentration, the viscosity of waterborne polymeric mixture can reduce when mixing with formation water, thus change Become the mobility ratio of waterborne polymeric mixture and the oil in stratum and waterborne polymeric may be reduced Mixture suppression mixture fingering is through the effect of the oil in stratum.Additionally, have relative to water The formation water of the property higher bivalent cation content of polymeric blends can be due to polymers for divalent The affinity of cation and the polymer of precipitation mixture, may reduce the permeability on stratum.As Really the bivalent cation content of formation water is less than the bivalent cation content of waterborne polymeric mixture And/or if owing to exchange with formation rock ion and make substantial amounts of bivalent cation gather from aqueous Polymer mixtures is peeled off, and the viscosity of waterborne polymeric mixture can improve, and thus may suppression mix Stratum is passed through in compound flowing.Additionally, due to waterborne polymeric mixture with have relative to aqueous The formation water contact of the higher bivalent cation content of polymeric blends may cause formation damage Swelling with clay, this is because due to the affinity of polymers for divalent cations, polymerizable aqueous Thing mixture can peel off bivalent cation from stratum and formation water, causes clay deflocculation.

The method improved is needed to keep the viscosity introducing the waterborne polymeric mixture carrying oil formation From stratum output oil.

Summary of the invention

The present invention relates to a kind of from carrying the method that oil formation output is oily, including:

Determine the bivalent cation mass action relative to monovalent cation of the water carrying oil formation Ratio, wherein carries the bivalent cation of water of oil formation relative to the mass action ratio of monovalent cation Defined by formula (I):

(I)MAR_fw=[C⁺ _(fw)]²/C²⁺ _(fw)

Wherein MAR_fwFor the mass action ratio of bivalent cation and the monovalent cation of formation water, C⁺ _(fw)For the monovalent ion concentration in formation water, and C²⁺ _(fw)Dense for the bivalent cation in formation water Degree；

The aqueous displacement fluid of the polymer comprising water and ion live-wire, wherein said aqueous are provided The water of displacement fluid has the total of 200 parts per million part (ppmw)-5,000ppmw and dissolves admittedly Body burden and bivalent cation relative to the mass action of monovalent cation than for MAR_fw's 70-130%, the bivalent cation of the water of wherein said aqueous displacement fluid and the matter of monovalent cation Amount effect defines than by formula (II):

(II)MAR_adf=[C⁺ _(adf)]²/C²⁺ _(adf)

Wherein MAR_adfBivalent cation and the matter of monovalent cation for described aqueous displacement fluid Amount effect ratio, C⁺ _(adf)For the monovalent ion concentration in described aqueous displacement fluid, and C²⁺ _(adf)For Divalent cation concentration in described aqueous displacement fluid；

Aqueous displacement fluid is introduced and carries oil formation with the oil in stratum described in displacement；

From described stratum output oil after aqueous displacement fluid is introduced load oil formation.

Accompanying drawing explanation

The figure of Fig. 1 is the ion filter that can be used for the inventive method.

The figure of Fig. 2 is the ion filter that can be used for the inventive method.

The figure of Fig. 3 is the ion filter that can be used for the inventive method.

The figure of Fig. 4 is oily output and the piece-rate system that can be used for the inventive method.

The figure of Fig. 5 is the well distribution of the oily output that can be used for the inventive method.

Fig. 6 figure represent inject carry the synthesis formation brine of oil rock core, design Low-salinity water-soluble Sodium and calcium in the effluent of the low salinity water solution of liquid, high salinity polymer solution and design are dense Degree.

Fig. 7 figure represent inject carry the synthesis formation brine of oil rock core, design Low-salinity water-soluble Magnesium and potassium in the effluent of the low salinity water solution of liquid, high salinity polymer solution and design are dense Degree.

The figure of Fig. 8 represents high salinity polymer solution and the Low-salinity of design injecting load oil rock core The viscosity of the effluent of polymer solution.

Detailed description of the invention

The present invention relates to a kind of method, wherein will comprise and have 200-5, the total of 000ppm is dissolved admittedly The aqueous displacement fluid of the water of body (" TDS ") content and the aqueous dispersion polymers of ion live-wire draws Enter the load oil formation comprising oil and water, with the holding aqueous when contacting with the water in stratum and stratum The viscosity of displacement fluid.May select or design the viscosity of aqueous displacement fluid with in terms of mobility With the oil in stratum under formation temperature conditions compatible, thus aqueous displacement fluid can be with substantially Upper class plug flow drives the oil of flowing to pass through stratum, and does not has obvious aqueous displacement fluid Fingering passes through aqueous displacement fluid by oily or oily fingering.The viscosity of aqueous displacement fluid can be water Divalent cation concentration in the type of polymer and concentration and aqueous displacement fluid in property displacement fluid Function wherein divalent cation concentration can be by it on the impact of the polymer of ion live-wire Affect the viscosity of aqueous displacement fluid.Before aqueous displacement fluid is introduced stratum, optional Or the ionomer material of design aqueous displacement fluid and bivalent cation content have to provide The aqueous displacement fluid of viscosity, described viscosity effectively makes the mobility of aqueous displacement fluid effectively make It drives the oil of flowing in stratum with substantially class plug flow under formation temperature conditions.

In the methods of the invention, can pass through to select or the ion concentration of design aqueous displacement fluid, Make the bivalent cation of aqueous displacement fluid and the mass action ratio (" MAR ") of monovalent cation Comparable with the MAR of monovalent cation with the bivalent cation of formation water and formation rock or basic phase With, aqueous displacement fluid is introduced carry oil formation and with formation water and stratum clay, rock and/ Or during mineral contact, keep viscosity and the relative flow of aqueous displacement fluid.As answered herein , aqueous displacement fluid or formation water or the bivalent cation of formation rock and monovalent cation MAR be defined as the concentration of monovalent cation of aqueous displacement fluid or formation water or formation rock Summation square with the ratio of the concentration summation of bivalent cation, or MAR=(C⁺)²/(C²⁺), its Middle C⁺For by milliequivalent/liter in terms of the concentration summation of all monovalent cation materials, and C²⁺For with This definition of concentration summation of all bivalent cation materials of milliequivalent/liter meter is based on following vacation Surely the concentration utilizing concentration summation rather than routine is amassed and is simplified calculating: monovalent cation reaction class Similar (such as, with bivalent cation reaction like (such as, as material, compared to bivalent cation) As material, compared to monovalent cation).When used herein, " MAR " refers to bivalence sun Ion and the MAR of monovalent cation.MAR and formation water MAR and ground when aqueous displacement fluid (they are similar to layer rock MAR, because cation exchange is between formation water and formation rock Poised state) than time, when aqueous displacement fluid contacts with formation water and formation rock in aqueous Bivalent cation and the ratio of monovalent cation in displacement fluid, formation water and formation rock are basic Do not change.Therefore, the viscosity of aqueous displacement fluid will not due to aqueous displacement fluid with The change of the ratio of bivalent cation and monovalent cation when stratum contacts with formation water and increase and add deduct Little, and be used for making oil flowing at aqueous displacement fluid and be driven through stratum with during from stratum output, The viscosity of aqueous displacement fluid is positively retained at or close to for suppressing aqueous displacement fluid fingering to pass through The optimum viscosity of formation oil or vice versa.

The inventive method comprises determining that the MAR of the water carrying oil formation；Offer comprises water and ion The aqueous displacement fluid of charged polymer, wherein the water of aqueous displacement fluid has 200 weight Total dissolved solidss (" the TDS ") content of part/million parts of (ppmw)-5,000ppmw and MAR are ground The 70-130% of the MAR of layer water；Aqueous displacement fluid is introduced and carries oil formation with in displacement stratum Oil；Oily from stratum output with after aqueous displacement fluid is introduced stratum.

The MAR of formation water is defined by formula (I) herein:

(I)MAR_fw=(C⁺ _(fw))²/(C²⁺ _(fw))

Wherein MAR_fwFor the mass action ratio of bivalent cation and the monovalent cation of formation water, C⁺ _(fw)For in formation water by milliequivalent/liter in terms of the concentration summation of monovalent cation, and C²⁺ _(fw)For In formation water by milliequivalent/liter in terms of the concentration summation of bivalent cation.

The MAR of aqueous displacement fluid is defined by formula (II) herein:

(II)MAR_adf=(C⁺ _(adf))²/(C²⁺ _(adf))

Wherein MAR_adfThe matter of bivalent cation and monovalent cation for the water of aqueous displacement fluid Amount effect ratio, C⁺ _(adf)For in aqueous displacement fluid by milliequivalent/liter in terms of monovalent cation dense Degree summation, and C²⁺ _(adf)For in aqueous displacement fluid by milliequivalent/liter in terms of bivalent cation dense Degree summation.The inventive method can also include determining that in stratum, oil viscosity and offer viscosity are stratum The aqueous displacement fluid of the 10-500% of middle oil viscosity, wherein aqueous displacement fluid and oily gluing Degree can within the temperature range of stratum at a temperature of determine.

The bivalent cation of the water carrying oil formation can be identified below with the MAR of monovalent cation: obtains The sample of the water of oil formation must be carried, measure each bivalent cation material and each monovalence sun in formation water The concentration of ionic species, and calculate formation water MAR according to above-mentioned formula (I)_(fw).Carry the water of oil formation Sample can according to output well known by persons skilled in the art oil conventional method obtain.Such as, Formation water can be by extracting fluid from stratum out by well and separating formation water with other produced fluid such as Oil obtains.In formation water sample, divalent cation concentration and the monovalence of bivalent cation material are positive The monovalent ion concentration of ionic species can normal according to analytical chemistry well known by persons skilled in the art Rule method determines.

After determining the MAR of formation water, it is provided that comprise water and the water of water dispersible ionomer Property displacement fluid, its TDS content with 200-5,000ppm and MAR are the MAR of formation water 70-130%.Can be from there is the TDS content of 200-5,000ppm and MAR is the MAR of formation water 70-130% open water supply provide aqueous displacement fluid water.Alternatively, can be from having The extraneous TDS content of 200-5,000ppm and/or MAR are less than the 70% of the MAR of formation water Or higher than formation water MAR 130% water source provide aqueous displacement fluid water, wherein process Described water source in the range of 200-5,000ppm, or processes described water source with regulation TDS content To regulate the 70-130% of its MAR to the MAR of formation water, or process described water source to regulate TDS Content is in the range of 200-5,000ppm and regulates its MAR to the MAR of formation water 70-130%.

The water of aqueous displacement fluid can carry from the water source of the TDS content with 200-5,000ppm Confession, or can be from having less than 200ppm or higher than 5, the water source of the TDS content of 000ppm provides, It is processed to the water to the TDS content with 200-5,000ppm.The water of aqueous displacement fluid can From Low-salinity open water supply such as aquifer, lake, from carry the water of oil formation output or include containing The river of the water of 200-5,000ppm total dissolved solidss provides, and wherein said water source can be used as water The water of property displacement fluid, and need not be processed to regulate the TDS content at described water source.

In another embodiment, the water of aqueous displacement fluid can be by processing from Low-salinity Open water supply such as aquifer, lake or river or the water from load oil formation output provide, wherein The water of natural origin or load oil formation has 0ppm to the TDS content less than 200ppm.TDS Content is that the TDS content of the 0ppm water extremely less than 200ppm can be by adding one or more water Soluble such as NaCl and/or CaCl₂Regulate to 200-5,000ppm to water.A kind of or many Plant water soluble salt to add to water source as the aqueous solution of salt, or can add in solid form To water source.

In another embodiment, the water of aqueous displacement fluid or its can pass through at least partially Process saline water source to provide.The TDS content at pending saline water source can be higher than 10,000ppm, or at least 20,000ppm, or at least 25,000ppm, or at least 30,000ppm, Or at least 35,000ppm, or at least 40,000ppm, or at least 50,000ppm, or 15,000-250,000ppm, or 20,000-200,000ppm, or 25,000-150,000ppm, Or 30,000-100,000ppm, or 35,000-50,000ppm.Pending to provide aqueous to drive For the saline water source of the water of fluid be selected from aquifer water, sea water, brackish water, Jiang Koushui, from Carry water and their mixture of oil formation output.

Referring now to Fig. 1, have higher than 10 as mentioned above, the saline of the TDS content of 000ppm Water source can carry out processing to produce extremely by making saline water source 111 contact with ion filter 113 The water of at least part of aqueous displacement fluid, the mechanism being wherein used for processing saline water source can include Ion filter.A part of water source 111 can be treated to be formed by ion filter 113 Having the water 115 of the salinity reduced relative to water source 111, the TDS of the most treated water contains Measure and can be up to 5,000ppm, and more preferably 200-5,000ppm, and most preferably 500-4,000ppm.The most treated water 115 can be used as at least one of aqueous The water of displacement fluid.

A part of water source 111 can not be had relative to water source to be formed by ion filter 113 The saline seepage remaining liquid 117 of the salinity improved.The TDS content of saline seepage remaining liquid can be at least 20,000ppm, or 25,000-300,000ppm.At least some of saline seepage remaining liquid can be as hereafter Describe in further detail and utilize.

If the MAR of treated water is higher than the 130% of formation water MAR or less than formation water MAR 70%, the water that scalable is treated, so that the MAR of treated water is the MAR of formation water 70-130%.Salt containing monovalent cation or its aqueous solution or the salt containing bivalent cation or Its aqueous solution can be used for regulating the MAR of treated water up or down so that treated water The 70-130% of the MAR that MAR is formation water.If it is required, at least some of saline oozes remaining Liquid 117 may be added to that treated water 115 is to regulate the MAR of treated water to formation water The 70-130% of MAR.The treated water that at least one of MAR is adjusted can be used as aqueous and drives Water for fluid.

Ion filter 113 can be the system based on film utilizing ion isolation film device, described Ion isolation film device is selected from nanofiltration film device, reverse osmosis membrane apparatus and combinations thereof. Nanofiltration film device can include that one or more are effective to or selectivity removing preferential from water source The nano-filtration membrane of multivalent ion (including bivalent cation), thus treated water can comprise Less than 80% compared to the water source of charging to nano-filtration membrane or it is less than 90% or is less than the multivalence of 95% Ion and/or bivalent cation, and seepage remaining liquid can comprise the multivalence increased accordingly relative to water source Ion and/or bivalent cation.One or more nano-filtration membrane of nanofiltration film device also may be used With the monovalent ion content of moderate reduction charging to the water source of nano-filtration membrane, the most treated The water source that water can comprise relative to feeding to nano-filtration membrane less than 20% or is less than 30% or low In 50% or monovalent ion less than 70%, and saline seepage remaining liquid can comprise corresponding relative to water source The monovalent ion increased.Nano-filtration membrane can by charged polymeric material (such as have carboxylic acid, sulfonic acid, Amine or amide functional group) formed, described charged polymeric material include polyamide, cellulose acetate, Piperazine or substituted piperazine film, wherein the thin ion identification layer of film is supported on thicker porous material On, described thicker porous material is clipped between identification layer and back lining materials.Can be used for ion mistake The commercially available sheet form being suitable for of the nanofiltration film device in filter 113 or spiral winding shape The nano-filtration membrane of formula includes but not limited to: SEASOFT8040DK, 8040DL, and SEASAL DS-5 (purchased from GE Osmonics, Inc., 5951Clearwater Drive, Minnetonka, MN55343, United States)；NF200 is serial, and NF-55, NF-70, and NF-90 (purchase From Dow FilmTec Corp., 5239W.73^rdSt., Minneapolis, MN, 55345, United States)；DS-5 and DS-51 (purchased from Desalination Systems, Inc., 760Shadowridge Dr., Vista, CA, 92083, United States)；ESNA-400 (purchases From Hydranautics, 401Jones Road, Oceanside, CA92508, United States)；With TFCS (purchased from Fluid Systems, Inc., 16619Aldine Westfield Road, Houston, TX77032, United States).

The reverse osmosis membrane apparatus that can be used for ion filter 113 can include one or more effective In substantially removing the reverse osmosis membrane of all ions (including monovalent ion) from water source, thus through place The water of reason can comprise the water source relative to charging to reverse osmosis membrane less than 85% or less than 90% or Ion less than 95% or less than 98%, and saline seepage remaining liquid can comprise and increase accordingly relative to water source The ion added.Reverse osmosis membrane can be spiral winding or doughnut membrane module, and can be by single Asymmetric membrane prepared by polymeric material, such as asymmetrical fibre element acetate membrane, or by the first He Film composite material film prepared by the second polymeric material, the aromatics of the crosslinking such as combined with polysulfones Polyamide.Can be used for reverse osmosis membrane apparatus in ion filter 113 be suitable for commercially available Reverse osmosis membrane includes but not limited to: AG8040F and AG8040-400 (purchased from GE Osmonics)； SW30 series and LF (purchased from Dow FilmTec Corp.)；DESAL-11 (is purchased from Desalination Systems, Inc.)；ESPA (purchased from Hydranautics)；ULP (purchases From Fluid Systems, Inc.)；With ACM (purchased from TriSep Corp., 93S.La Patera Lane, Goleta, CA93117, United States).

Generally, when filtered brine water source 111 is to reduce the TDS content at water source and to produce treated Water 115 time, need the osmotic pressure bringing pressure to bear on ion filter 113 to overcome film both sides. The pressure putting on ion filter 113 can be at least 2.0MPa, or at least 3.0MPa, or extremely Few 4.0MPa, and can at most 10.0MPa, or at most 9.0MPa, or most 8.0MPa, and can For 2.0-10.0MPa, or 3.0-9.0MPa.Put on the nanometer mistake in ion filter 113 The pressure of filter membrane can be the lower value of the pressure limit relative to the pressure putting on reverse osmosis membrane. The pressure of the nanofiltration film device putting on ion filter 113 can be 2.0-6.0MPa, and The pressure of the reverse osmosis membrane apparatus putting on ion filter 113 can be 4.0-10.0MPa.As Really ion filter 113 includes film device nanofiltration, reverse osmosis or both tandem compounds, The pressure of each film putting on film device can be less than previous film device at least 0.5MPa, because needing Relatively low pressure is wanted to overcome the osmotic pressure of the penetrating fluid at first film device.

Referring now to Fig. 2, ion filter 113 can include the first ionic membrane dress being arranged in series Putting 119 and one or more second ion-exchange membrane facility 121, the most each ion-exchange membrane facility can be to receive Rice filtration film device or reverse osmosis membrane apparatus.There is TDS higher than 10,000ppm as mentioned above The saline water source 111 of content can contact with the first ion-exchange membrane facility 119 so that at least some of salt Water water source is contained relative to the TDS of saline water source reduction to be formed to have by the first ion-exchange membrane facility The penetrating fluid 123 of amount, the TDS content of wherein said penetrating fluid can be at least 1,000ppm, or At least 2,500ppm, or at least 5,000ppm, or at least 7,000ppm, or at least 10,000ppm, or at least 15,000ppm.A part of saline water source can not pass through the first ionic membrane Device 119 has the primary brine seepage remaining liquid 125 of the salinity improved relative to water source to be formed. Penetrating fluid 123 can contact so that oozing at least partially with each second ion-exchange membrane facility 121 in order Transparent liquid is formed by each second ion-exchange membrane facility has the salinity relative to penetrating fluid 123 reduction Treated water 115 and saline water source 111, the most treated water can have 200-5,000ppm TDS content.The most treated water 115 can be used as at least one of aqueous and drives Water for fluid.

A part of penetrating fluid 123 can not by each one or more second ion-exchange membrane facility 121 with Form one or more second saline seepage remaining liquid 127.Primary brine seepage remaining liquid 125, one or many Individual second saline seepage remaining liquid 127 or primary brine seepage remaining liquid 125 and one or more second saline The combination of seepage remaining liquid 127 can form the saline seepage remaining liquid 117 from ion filter 113, its Middle saline seepage remaining liquid 117 has the salinity improved relative to water source 111 and can have at least The TDS content of 20,000ppm or 25,000-300,000ppm.By primary brine seepage remaining liquid 125, At least some of saline that one or more second saline seepage remaining liquids 127 or combinations thereof are formed Seepage remaining liquid 117 can as further detailed below utilize.

Referring now to Fig. 3, ion filter 113 can include the first ionic membrane dress being arranged in parallel Putting 129 and second ion-exchange membrane facility 131, wherein the first ion-exchange membrane facility can include one or many Individual nano-filtration membrane or one or more reverse osmosis membrane or combinations thereof, and the second ionic membrane dress Put and can include one or more nano-filtration membrane, one or more reverse osmosis membrane or combinations thereof. The Part I 133 at saline water source 111 can contact with the first ion-exchange membrane facility 129 as mentioned above Tool can be formed by the first ion-exchange membrane facility 129 with a part for saline water source 133 Part I There is the first penetrating fluid 135 of the TDS content reduced relative to saline water source 111.First infiltration The TDS content of liquid 135 less than 10,000ppm, or can be less than 7,500ppm, or is less than 6,000ppm, or less than 5,000ppm, or be 200-5,000ppm.Saline water source 133 A part for a part can not be formed by the first ion-exchange membrane facility 129 to be had higher than saline water source First saline seepage remaining liquid 137 of the TDS content of 111.The TDS of the first saline seepage remaining liquid 137 Content can be at least 20,000ppm, or at least 25,000ppm, or at least 30,000ppm, or At least 35,000ppm, or at least 40,000ppm, or at least 50,000ppm.Saline water source The Part II 139 of 111 can contact with the second ion-exchange membrane facility 131, and saline water source 139 A part for Part II can be formed by the second ion-exchange membrane facility 131 to be had relative to saline water Second penetrating fluid 141 of the TDS content that source 111 reduces.The TDS content of the second penetrating fluid can Less than 10,000ppm, or less than 7,500ppm, or less than 5,000ppm, or it is 200-5,000ppm.A part for saline water source 139 Part II can not pass through the second ionic membrane It is at least 20,000ppm or at least 25,000ppm or at least that device 131 forms TDS content 30,000ppm or at least 25,000ppm or at least 40,000ppm or at least 50,000ppm The second saline seepage remaining liquid 143.First penetrating fluid 135 and at least the one of the second penetrating fluid 141 Part may be combined to form TDS content and is at most 5,000ppm or is less than 40,000ppm or is The treated water 115 of 200-5,000ppm, a part of treated water 115 of at least a part of which can Water for use as aqueous displacement fluid.First saline seepage remaining liquid 137, one part, the second salt Water seepage remaining liquid 143, one part, the first saline seepage remaining liquid 137 and the second saline seepage remaining liquid 143 Combination or their combination of a part can form saline seepage remaining liquid 117, saline seepage remaining liquid 117 Can as further detailed below utilize.

In one embodiment, the first ion-exchange membrane facility 129 can be by one or more nanometer mistakes Filter membrane composition and the second ion-exchange membrane facility 131 can be made up of one or more reverse osmosis membranes.Pass through Second penetrating fluid 141 of the second ion-exchange membrane facility 131 can have the TDS content less than 200ppm, Condition is that one or more reverse osmosis membranes of the second ion-exchange membrane facility 131 remove from saline water source 111 Go substantially all of total dissolved solidss.By can in the first penetrating fluid 135 of nano-filtration membrane There is enough monovalent ions to have at least 200ppm or at least 1,000ppm or at least The TDS content of 2,000ppm, thus the first and second penetrating fluids combined are formed and have The treated water 115 of the TDS content of 200-5,000ppm.

Referring now to Fig. 1,2 and 3, if treated water 115 has less than 200ppm's TDS content, the TDS content of the water that scalable is treated makes the TDS content of treated water be 200-5,000ppm.A part of saline seepage remaining liquid 117 may be added to that treated water 115 is to adjust Joint TDS content is from less than 200ppm to 200-5,000ppm.Alternatively, one or more salt Or aqueous salt solution such as NaCl and/or CaCl₂Salt or aqueous salt solution may be added to that treated Water 115 is with the TDS content of the treated water of regulation to 200-5,000ppm.At least some of institute Treated water after the TDS regulation obtained can be used as the water of aqueous displacement fluid.

The MAR of the water of aqueous displacement fluid is also the 70-130% of the MAR of formation water.Aqueous is driven The water source of the 70-130% being selected from the MAR that MAR is formation water for the water of fluid maybe can process institute State the 70-130% that the water at water source makes the MAR that MAR is formation water of water.Water source can be treated Water, described water source the most treated with regulation water TDS content to 200-5,000ppm, as above Described.In an embodiment of the inventive method, as mentioned above to Low-salinity open water supply Or the water at saline water source carries out processing to regulate the TDS content of water to 200-5,000ppm, then Treated water after regulating TDS processes the treated water after regulating TDS regulation The 70-130% of MAR to the MAR of formation water, keep the TDS of the water after MAR regulation simultaneously Content is 200-5,000ppm.In another embodiment, natural to Low-salinity as mentioned above The water at water source or saline water source carries out the MAR that processes to regulate water to the MAR of formation water 70-130%, after the water after then regulating MAR as mentioned above processes to regulate MAR regulation The TDS content of water to 200-5,000ppm, keep the MAR that MAR is formation water of water simultaneously 70-130%.In another embodiment, as mentioned above to having 200-5,000ppm's The MAR of the water of the Low-salinity open water supply of TDS content carries out the MAR processing to regulate water to ground The 70-130% of the MAR of layer water, keeps the TDS content model at 200-5,000ppm of water simultaneously In enclosing.In another embodiment, low to the 70-130% of the MAR that MAR is formation water The TDS content of the water at salinity open water supply or saline water source carries out processing to regulate TDS content extremely 200-5,000ppm, keep the MAR scope at the 70-130% of the MAR of formation water of water simultaneously In.In another embodiment, the water of aqueous displacement fluid is selected from having The water source of the 70-130% of the TDS content of 200-5,000ppm and MAR that MAR is formation water.

MAR for bivalent cation and the monovalent cation of the source water of aqueous displacement fluid can It is identified below: to measure each bivalent cation material in water and the concentration of each monovalent cation material, With the MAR calculating water according to upper formula (II)_(adf).Bivalent cation material in water bivalence sun from The monovalent ion concentration of sub-concentration and monovalent cation material can be according to known to those skilled in the art The conventional method of analytical chemistry determine.

If it is required, can regulate as follows for the MAR of the water of aqueous displacement fluid: 1) calculate and adjust Save needed for the MAR to the 70-130% of the measurement MAR of formation water of the water of aqueous displacement fluid Monovalent cation and/or the amount of bivalent cation；With 2) add in water or remove amount of calculation Monovalent cation and/or bivalent cation with the MAR of the MAR of regulation water to formation water 70-130%.

Monovalent cation and/or bivalent cation may be added to that in the water of aqueous displacement fluid With the MAR's of the MAR of bivalent cation and the monovalent cation of regulation water to formation water 70-130%.Can by add one or more selected monovalent cation salt a selected amount of and/or One or more selected divalent cation salt or add one or more monovalencies a selected amount of Cationic salts and/or the aqueous solution of divalent cation salt that one or more are selected, by monovalence sun from Son and/or bivalent cation add to water.In an embodiment of the inventive method, as The upper described one or more saline seepage remaining liquids produced in reducing the process of the water of TDS content of water 117,125,127,137 or 143 may be added to that in water to regulate the MAR of water to formation water 70-130%.

Monovalent cation and/or bivalent cation can remove from the water being ready to use in aqueous displacement fluid Remove the 70-130% regulating the bivalent cation of water with the MAR of monovalent cation to formation water. As described above by passing water through nano-filtration membrane, can be relative to monovalent cation preferentially from water Middle removing bivalent cation.By pass water through be filled with selective absorption monovalent cation from The ion exchange column of sub-exchange material, preferentially can remove one from water relative to bivalent cation Valency cation.

Aqueous displacement fluid also comprises the water dispersible, the most water-soluble being dispersed in water as mentioned above Property ionomer.There is TDS content and the bivalence sun of 200-5,000ppm in selection or generation The bivalent cation that MAR is formation water of ion and monovalent cation and the MAR of monovalent cation 70-130% water after, viscosity that the polymer of ion live-wire mixes with water to increase it and Produce aqueous displacement fluid.The addition of the polymer of ion live-wire can be effectively increased treated The viscosity of water to oil in carrying in oil formation the load oil formation measured at a temperature of in temperature range The 10-500% of viscosity.The addition of the polymer of ion live-wire can be relative to formation crude The mobility of position oil effectively reduces the mobility of treated water, preferably makes gained aqueous displacement stream Body is relative to carrying in oil formation the mobility of oil ratio for 0.2-5.

The polymer being mixed to form aqueous displacement fluid with water can be for strengthening oil recovery application The polymer of any ion live-wire, wherein polymer is solvable or can be dispersed in water.Polymerization Thing can be homopolymer or the heteropolymer comprising two or more monomeric units.According to mixed in water Heshui dissolubility or the Conventional wisdom of aqueous dispersion polymers, optional mix with treated water The ratio of the monomeric unit of heteropolymer has the aqueous displacement fluid of selected viscosity to provide.Polymerization Thing can be water-soluble polyacrylamide or polyacrylate.Polymer can be the polymerization of partial hydrolysis Thing.The polymer of the partial hydrolysis for mixing with treated water can have 0.1-0.4 or The degree of hydrolysis of 0.2-0.3.For aqueous displacement fluid preferred polymers for have 0.15-0.4, The polyacrylamide of the partial hydrolysis of the degree of hydrolysis of preferably 0.2-0.35.For aqueous displacement fluid Preferred polymers be that SNF SAS is with trade name FLOPAAM^TM, particularly FLOPAAM^TM 3330 And FLOPAAM^TMThe polyacrylamide of the 3630 commercially available partial hydrolysiss sold.

Can be by adding polymer in water or add and add water in polymer and utilize mixing water and water Any Conventional mechanisms mixing of dissolubility or aqueous dispersion polymers comes mixed polymer and aqueous displacement The water of fluid.Can mixed polymer and water formation by stirring polymer in stirred tank and water Aqueous displacement fluid.Excessive shear should be avoided to divide with suppression polymer when mixed polymer and water The machinery reduction of sub-size.

Can carry with solidapowder form or the concentrated aqueous solution comprising 5-25wt% polymer form For polymer for mixing with water.If providing polymer to be used for mixing with solidapowder form, Water and polymer should mix time enough to allow hydrated polymer.

Optional and water is mixed to form the tool that the amount of polymers of aqueous displacement fluid is formed with offer There is the selected viscosity carrying oil formation situ oil relative to aqueous displacement fluid the most to be introduced Aqueous displacement fluid.The viscosity of polymer solution is polymer, its molecular weight, polymer Degree of hydrolysis, the salinity of polymer solution, the pH of solution, solution temperature, shear rate and solution The function of the concentration of middle polymer.The optional amount of polymers mixed with water has selected with offer The aqueous displacement fluid of viscosity, this is because polymer, its molecular weight, its degree of hydrolysis, water The salinity of the water of property displacement fluid and the temperature (relative to formation temperature) of pH and aqueous displacement fluid It is fixing, and shear rate can be protected by controlling the pressure on aqueous displacement fluid injection stratum Hold constant.Selected viscosity can be to carry oil formation situ oil to determine under formation temperature conditions 10-500% or 40-400% of viscosity.Formation crude position oil viscosity under formation temperature conditions can Determine according to the conventional method of this area.The selected viscosity of aqueous displacement fluid can be 0.5mPa s (cP)-250mPa s (cP), as measured at a temperature in the range of formation temperature conditions 's.

The amount of polymers provided in aqueous displacement fluid can also be selected to provide aqueous displacement fluid Relative to the selected mobility ratio of oil in stratum.Aqueous displacement fluid is oily selecting with stratum Mobility ratio can be 0.2-5 or 0.5-3.

In aqueous displacement fluid amount of polymers can be at least 350ppmw of aqueous displacement fluid extremely 10,000ppmw.In aqueous displacement fluid, amount of polymers can be aqueous displacement fluid 500-5,000ppmw or 1,000-2,500ppmw.

Aqueous displacement fluid is introduced and carries oil formation to be replaced by body and to make the oil flowing in stratum use In strengthening from stratum recovery of oil from stratum output.Carry oil formation can comprise porous matrix material, Oil and connate water.Load oil formation comprises can be from stratum after aqueous displacement fluid introduces stratum Separate and the oil of output.

The porous matrix material on stratum can comprise selected from porous mineral substrate, porous rock substrate, One or more porous matrix material of combination with porous mineral substrate and porous rock substrate. Formation temperature can be 5-275 DEG C, or 50-250 DEG C；Strata pressure can be 1-100MPa；Stratum The pH of middle connate water can be 4-9 or 5-8；Can be 2000-300,000ppm with the salinity of connate water TDS content.

The rock on stratum and/or mineral porous matrix material can comprise sandstone and/or selected from white clouds The carbonate wherein limestone of stone, limestone and their mixture can be microcrystal or crystal Limestone.The mineral that can form mineral porous matrix material can be clay or transistion metal compound. The clay that can form at least some of mineral porous matrix material includes smectic clays, terre verte/Erie Stone clay, montmorillonitic clay, illite clay, illite/micaceous clay, pyrophillite clay, Glauconite clay and kaolin clay.The mistake of at least some of mineral porous matrix material can be formed Cross metallic compound mineral and include carbonate and oxide, such as ferrum oxide, siderite and plagioclase Stone.

Porous matrix material can be the host material of consolidation, wherein forms the biggest of host material The most substantially all rock and/or mineral are consolidation, thus in rock and/or ore deposit In the material that thing is formed, when oil, aqueous displacement fluid or other fluid pass therethrough, substantially Upper whole rocks and/or mineral are motionless.When oil, aqueous displacement fluid or other fluid from In by time, the rock of preferably at least 95wt% or at least 97wt% or at least 99wt% and/ Or mineral are motionless, thus by oil, aqueous displacement fluid or other fluid by and shift The rock of any amount or mineral material are not enough to cause stratum to flowing through the oil on stratum, aqueous displacement Fluid or other fluid are impermeable.Alternatively, porous matrix material can be unconsolidated Host material, wherein forms at least most of of host material or substantially all rock and/or ore deposit Thing is unconsolidated.No matter by the mineral substrate consolidated, unconsolidated mineral substrate or they Combination is formed, and the permeability on stratum can be 0.00001-15 darcy or 0.001-1 darcy.

Carrying oil formation can be subsurface formations.Subsurface formations can include that one or more are many as mentioned above Pore matrix material, wherein porous matrix material be positioned at can be located under earth's surface deep 50-6000 rice, Or the lower section of the superstratum of 100-4000 rice or 200-2000 rice.Subsurface formations can be sea Stratum, the end.

Carry in oil formation the oil comprised at formation condition (particularly within the temperature range of stratum Temperature) under viscosity can be at least 0.2mPa s (0.2cP), or at least 1mPa s (1cP), Or at least 5mPa s (10cP), or at least 10mPa s (100cP).Carry in oil formation and comprise Oil viscosity under formation temperature conditions can be 0.2-10,000mPa s (0.2-10,000 CP) or 1-1,000mPa s (1-1,000cP) or 1-500mPa s (1-500cP) or 1-250mPa·s(1-250cP).Preferably carry the gluing under formation temperature conditions of the oil in oil formation Degree is for 0.2-500mPa s so that can provide the mobility ratio and not with most relative to oil 2 Comprise the aqueous displacement fluid of excess polymeric.

Oil in load oil formation can be located in the hole in the porous matrix material on stratum.Load can be made The oil of oil formation does not flows in the hole in the porous matrix material on stratum, such as, by hair Tubule power, oil and oil and the interface of water in the interaction of pore surface, oil viscosity or stratum Tension force realizes.

Carrying oil formation and also can comprise water, water can be located in the hole in porous matrix material.Stratum In water can be connate water, secondary or the water of three oil recovery processes water drives or their mixture. The TDS content carrying the connate water in oil formation can be at least 500ppm, or at least 1,000ppm, Or at least 2,500ppm, or at least 5,000ppm, or at least 10,000ppm, or at least 25,000ppm, or 500-250,000ppm, or 1,000-200,000ppm, or 2,000-100,000ppm, or 2,500-50,000ppm, or 5,000-45,000ppm.Carry Connate water in oil formation can have at least 50ppm or at least 100ppm or at least 150ppm Multivalent ionic content, and can have 50-40,000ppm or 100-20,000ppm or The multivalent ionic content of 150-15,000ppm.The divalent ion carrying the connate water in oil formation contains Amount can be at least 20ppm, or at least 40ppm, or at least 50ppm, or at least 100ppm, or 20-35,000ppm, or 40-20,000ppm, or 50-15,000ppm.Preferably in stratum Connate water is up to the total dissolved solidss of appropriate amount and relatively low intensity of polyvalent cation, Total polyvalent cation of the TDS content and most 250ppm that preferably have up to 30,000ppm contains Amount.

The water in load oil formation can be made to be positioned such that, and intrapore oil does not flows.By aqueous displacement stream Body introduces stratum can make at least some of oil flowing in stratum for by the hole in stratum Middle release at least partly oil and from stratum output and gathering.Can by aqueous displacement fluid introducing stratum Make oil flowing for by with the form of class piston flow drive oily by stratum therefrom output.

Introduce stratum and make aqueous displacement fluid and formation water and with stratum clay, mineral and During rock contact, due to aqueous displacement fluid and the bivalent cation of formation water and monovalent cation The Relative Equivalence of MAR, the viscosity of aqueous displacement fluid can be kept.By aqueous displacement stream Body introduces before stratum, the bivalence of formation water, oil and stratum clay, mineral and rock positive from Son and monovalent cation content are in relative equilibrium, therefore the bivalent cation of formation water and monovalence Cation concn, oil bivalent cation and monovalent cation concentration and stratum bivalence sun from Son and monovalent cation concentration relative constancy.Aqueous displacement fluid is introduced stratum so that therein Oil flowing will not bother this balance because the bivalent cation of aqueous displacement fluid and formation water with The MAR of monovalent cation is similar to, even if the TDS content of aqueous displacement fluid may be significantly different TDS content in formation water.Therefore, when contacting with formation water and formation rock, aqueous is driven For fluid viscosity will not owing to exchanging and significant change with formation water and formation rock ion, and The polymer of aqueous displacement fluid will not precipitate.

Referring now to Fig. 4, there is shown the present system for implementing the inventive method 200.The first well 201 that described system includes extending to as above carrying oil formation 205 and the Two wells 203.Carry oil formation 205 can include being positioned at below superstratum 213 as mentioned above by One or more ground layer segment 207,209 and 211 that porous material substrates is formed.There is provided as above Described aqueous displacement fluid.Aqueous displacement fluid can be by by the fluid-operated connection of pipeline 219 Aqueous displacement fluid storage facilities 215 to the first injection/output equipment 217 provides.First note Enter/output equipment 217 fluid-operated can be connected to the first well 201, it can inject from first/produce Go out equipment 217 to extend to carry oil formation 205.Aqueous displacement fluid can set from the first injection/output Standby 217 flow through the first well is introduced in such as the layer segment 209 of stratum 205, and wherein the first injection/ Output equipment 217 and the first well or the first well itself include for introducing ground by aqueous displacement fluid Mechanism in Ceng.Alternatively, aqueous displacement fluid can be from aqueous displacement fluid storage facilities 215 Flowing directly into the first well 201 for injecting in stratum 205, wherein the first well includes for by water Property displacement fluid introduce the mechanism in stratum.For aqueous displacement fluid is passed through the first well 201 Introduce the mechanism in stratum 205 (be positioned at the first injection/output equipment the 217, first well 201 or In Zhe Liangzhe) perforation for being delivered in the first well by aqueous displacement fluid or perforate can be included Pump 221, aqueous displacement fluid can be introduced ground by the perforation in described first well or perforate In Ceng.

Such as by aqueous displacement fluid is pumped into stratum by the first well 201, aqueous is driven Inject in stratum for fluid by the first well, aqueous displacement fluid can be introduced in stratum 205. Aqueous displacement fluid introduces the pressure in stratum to be laminated in instantaneous pressure up to ground from stratum Split pressure or exceed formation fracture pressure.The pressure that aqueous displacement fluid can inject stratum can be 10-95% or 20-90% of formation fracture pressure.May select and aqueous displacement fluid is injected stratum Pressure makes the depolymerization in aqueous displacement fluid to limit by shearing force, the most relatively low Injection pressure limits and makes depolymerization by shearing force.Preferably at formation fracture pressure Under the pressure of 10-50%, aqueous displacement fluid is injected in stratum.

The aqueous displacement fluid volume being introduced stratum 205 by the first well 201 can be 0.001-5 Times pore volume or 0.01-2 times of pore volume or 0.1-1 times of pore volume or 0.2-0.9 Times pore volume, wherein term " pore volume " refers between the first well 201 and the second well 203 Can be by the inswept formation volume of aqueous displacement fluid.Pass through method known to those skilled in the art Such as wherein comprise the water of tracer by stratum 205 from the by simulation study or by injecting One well 201 to the second well 203, is readily determined pore volume.

The oil flowing in stratum can be made to be used for from stratum output aqueous displacement fluid introducing stratum. When aqueous displacement fluid introduces stratum 205 by the first well 201, aqueous displacement fluid such as arrow Stratum is diffused into shown in 223.Aqueous displacement fluid and the oil in the porous matrix material on stratum Contact and promotion oil are used for from stratum output to the second well 203 by stratum.Aqueous displacement fluid Fingering can be by the aqueous relative to oil viscosity by aqueous displacement fluid by oily or oily fingering The viscosity of displacement fluid and suppress, and aqueous displacement fluid makes oil flowing in preferred embodiments Oil is driven to pass through stratum with the form of substantially class piston flow.

After aqueous displacement fluid is introduced in stratum, by further by more aqueous displacements Fluid or by introducing the water in stratum, can promote the oil of flowing and aqueous displacement fluid through ground Layer 205 is from the first well 201 to the second well 203.Aqueous displacement fluid is being fully introduced into stratum Afterwards, water can be introduced in stratum 205 by the first well 201 to promote or otherwise to drive The second well 203 is flowed to for output for aqueous displacement fluid and oil.

After aqueous displacement fluid is introduced stratum, can be stored in by the water on stratum to be introduced can By the fluid-operated water storage facilities being connected to the first injection/output equipment 217 of pipeline 227 225 neutralize therefrom offer water is used for introducing in stratum 205.Aqueous displacement fluid is being introduced ground After Ceng, the bivalent cation of the water on stratum to be introduced and the MAR of monovalent cation are preferably water Property displacement fluid the 70-130% of MAR of bivalent cation and monovalent cation, and preferably from For providing the source of the water for aqueous displacement fluid to provide water.First injection/output equipment 217 fluid-operated can be connected to the first well 201 to provide water for introducing stratum 205 to the first well In.Alternatively, water storage facilities 225 fluid-operated can be connected to the first well 201 with to first Well directly provides water to be used for introducing stratum 205.First injection/output equipment 217 and the first well 201 Or first well itself can include for introducing the water into the mechanism in stratum 205 by the first well 201. Can include for water is delivered to for being introduced the water into the mechanism on stratum 205 by the first well 201 Perforation in first well or the pump of perforate or compressor, wherein can by the perforation in the first well or Perforate injects water in stratum.For introducing the water into the machine in stratum 205 by the first well 201 Structure can be the pump 221 for injecting in stratum by aqueous displacement fluid by the first well 201.

Can introduce the water in stratum 205, as by water pump being sent by the first well to stratum Water is injected in stratum by the first well 201.Water can be injected stratum 205 by the first well 201 In pressure can be up to or exceed formation fracture pressure, or be formation fracture pressure 20-99% or 30-95% or 40-90%, or higher than formation fracture pressure, and preferably substantially Identical with for aqueous displacement fluid being injected the pressure on stratum.

After aqueous displacement fluid is introduced in stratum 205 by the first well 201, by the One well introduce the water yield on stratum can be 0.001-5 times of pore volume or 0.01-2 times of pore volume, Or 0.1-1 times of pore volume or 0.2-0.6 times of pore volume, wherein term " pore volume " Referring between the first well and the second well can be by the inswept formation volume of water.Introduce the water on stratum 205 Amount should be enough to drive the oil of flowing and aqueous displacement fluid through at least part of stratum.

By aqueous displacement fluid and optional water are introduced in stratum by the first well 201, can Make oil flowing for by the second well 203 from stratum 205 output, wherein as shown in arrow 229 Drive the oil of flowing by stratum for from the second well 203 output from the first well 201.At least one Part aqueous displacement fluid can from the first well 201 through stratum 205 to the second well 203 for The oil of flowing is together from stratum output.

After aqueous displacement fluid and optional water are introduced stratum 205 by the first well 201, Can be gathered by the second well 203 from stratum and output oil.Mechanism can be located at the second well for inciting somebody to action Aqueous displacement fluid is gathered and output oil from stratum, for adopting from stratum after introducing stratum 205 Receive and the mechanism of output oil also can gather from stratum after stratum being introduced by aqueous displacement fluid and Output at least one of aqueous displacement fluid, other water and/or gas.It is positioned at the second well 203 For gathering, the mechanism with output oil, aqueous displacement fluid, other water and/or gas can include pump 233, described pump 233 can be located in the second injection/output equipment 231 and/or the second well 203 In.Pump 233 can extract oil, at least some of by the perforation of the second well 203 from stratum 205 Aqueous displacement fluid, other water and/or gas to carry aqueous displacement oily, at least one of Fluid, other water and/or gas are to the second injection/output equipment 231.

Alternatively, for gathering from stratum 205 and output aqueous displacement oily, at least one of The mechanism of fluid, other water and/or gas can include can be located at the second injection/output equipment 231 In compressor 234.Compressor 234 can be stored up by the fluid-operated gas that is connected to of pipeline 236 Gas in tank 241, and compressible gas storage tank is for injecting stratum 205 by the second well 203. Compressor compressible gas to being enough to drive output oil from stratum by the second well 203, aqueous drives For fluid, other water and/or the pressure of gas, the most suitable pressure can pass through art technology Known to personnel, conventional method determines.Compression gas can the second Jing203Chu by be different from from The diverse location of the well location of stratum output oil, aqueous displacement fluid, other water and/or gas injects Stratum, such as, the gas of compression can inject stratum at ground layer segment 211, and at ground layer segment 209 from stratum output oil, aqueous displacement fluid, other water and/or gas.

Aqueous displacement stream oily, at least one of can be extracted from stratum 205 as shown in arrow 229 Body, other water and/or gas and along the second well 203 upwards output to the second injection/output equipment 231.Oil can be with gas and the part aqueous displacement fluid comprising output and from its of stratum output The aqueous mixture of its formation water such as water of connate water, circulating water or oil recovery water drive separates.Can Oil and the product of output is separated in the segregation apparatus 235 being positioned at the second injection/output equipment 231 The aqueous mixture gone out and the gas of output, in one embodiment, segregation apparatus 235 fluid It is operably connected to for gathering from stratum and output oil, the component of aqueous mixture and/or gas Mechanism 233.

TDS content is higher than 20,000ppm or be that the saline solution of 25,000-250,000ppm can There is provided to segregation apparatus 235 via pipeline 273 from saline solution storage facilities 247, for The oil of output and the aqueous mixture of output mix and optionally mix with the gas of output.Saline solution TDS content can be at least 20,000ppm or at least 25,000ppm or at least 30,000ppm or at least 40,000ppm or at least 50,000ppm or 20,000-250,000ppm or 25,000-200,000ppm or 30,000-150,000ppm, Or 40,000-100,000ppm.Saline solution be selected from sea water, brackish water, Jiangkou water or from Stratum output the output water separated with oil and/or the gas from stratum output.Alternatively, saline Solution can comprise as described above by making saline water source contact at least the one of output with ion filter Saline seepage remaining liquid 117, primary brine seepage remaining liquid 125 and/or the second saline seepage remaining liquid of part 127 or first saline seepage remaining liquid 137 and/or the second saline seepage remaining liquid 143 (such as institute in Fig. 1-3 Show).

Can also from demulsifier storage facilities 271 provide demulsifier to separation equipment 235, described Storage facilities 271 can be connected to segregation apparatus via pipeline 240 is fluid-operated.Demulsifier can carry It is supplied to separation equipment 235 for mixing with the oil of output, the water of output and saline solution, and appoints Choosing mixes with the gas of output, and the water of oil with output to promote output separates.

Demulsifier is selected from: amyl group resin；Butyl resin；Nonyl resin；Acid catalysis or alkali are urged The phenol-formaldehyde resin changed；Phenol-acrylate anhydride polyethyleneglycol resins；Polyurethane；Poly- Amine；Polyesteramine；Sulphonic acid ester；Diepoxide；Polyhydric alcohol；Ester and polyol ester, including three Alcohol fatty acid ester, triol adipate ester, and triol fumarate；Amyl group resin, butyl resin, The phenol-formaldehyde resin of nonyl resin, acid catalysis or base catalysis, fatty acid, polyamine, diepoxy Compound and the ethoxylation of polyhydric alcohol and/or propenoxylated compound；And combinations thereof；It Be dispersed in selected from dimethylbenzene, toluene, Heavy aromatic naphtha, isopropanol, methanol, 2- In the carrier solvent of ethyoxyl hexanol, diesel oil and combinations thereof.For separating from stratum 205 The oil of output and the demulsifier being suitable for of water can select by carrying out bottle test, and described bottle is tested It it is the conventional survey of the demulsifier for selecting to efficiently separate crude oil and water known to those skilled in the art Examination.Commercially available demulsifier includes: EB series (from National Chemical Supply, 4151SW 47^thAve., Davie, FL, 33314, United States), and Tretolite Demulsifier (from Baker Petrolite Corporation, 12645W.Airport Blvd., Sugar Land,TX 77478,United States)。

In embodiments of the present invention, as mentioned above at first time period the first well 201 Can be used for that aqueous displacement fluid and optional water are injected stratum 205 and the second well 203 can be used for From stratum output and separation oil, water and optional gas, with at second time period the second well 203 Can be used for aqueous displacement fluid and optional water being injected in stratum 205 so that the oil in stratum flows The oil that dynamic and driving is flowed is through stratum to the first well, and the first well 201 can be used for producing from stratum Going out and separate oil, water and gas, wherein the second time period is after the first period of time.Second note Enter/output equipment 231 can include mechanism's such as pump 251, described pump 251 is by pipeline 253 fluid It is operably connected to aqueous displacement fluid storage facilities 215, and the fluid-operated connection of described pump 251 To the second well 203 so that aqueous displacement fluid is introduced in stratum 205 by the second well.Pump 251 Also water storage facilities 225 can be connected to, with by aqueous displacement by pipeline 255 is fluid-operated Water is introduced stratum by the second well after introducing stratum 205 by the second well 203 by fluid.The One injection/output equipment 217 can include that mechanism such as pump 257 or compressor 258 are for by first Well 201 is from stratum 205 output oil, water and gas.First injection/output equipment 217 also can wrap Include by pipeline 260 fluid-operated be connected to mechanism 257 for separating the oil of output, output Water and the segregation apparatus 259 of gas of output, wherein segregation apparatus 259 can be similar to as above institute The segregation apparatus 235 stated.Saline solution storage facilities 247 can be fluid-operated by pipeline 272 It is connected to segregation apparatus 259 with offer saline solution to segregation apparatus 259, and demulsifier stores Equipment 271 can be by the fluid-operated segregation apparatus 259 that is connected to of pipeline 262 to provide demulsifier To segregation apparatus 259.Segregation apparatus 259 can be connected to liquid by pipeline 261 is fluid-operated Storage tank 237 is to store output and the oil of separation and to be grasped by pipeline 265 fluid in wet tank It is connected to gas reservoir 241 to store the gas of output in gas reservoir.

In first time period, the first well 201 can be used for by aqueous displacement fluid and optional subsequently Water introduce in stratum 205, and the second well 203 can be used for from stratum output and separates oil, water And gas；Then in the second time period, the second well 203 can be used for aqueous displacement fluid and appoints The water subsequently of choosing introduces in stratum 205, and the first well 201 can be used for from stratum output and divides From oil, water and gas, wherein first and second one cycle of composition time period.Can carry out multiple Cycle, including make the first well 201 and the second well 203 by aqueous displacement fluid and optional with After water introduce stratum 205 neutralize from stratum output and separate oil, between water and gas alternately, Wherein introduce and another well output and separation, then when second at one well of first time period Between section by they switch.One cycle can be about 12 hours-1 year or about 3 days-6 months, Or about 5 days-3 months.Aqueous displacement fluid can be introduced in stratum in the beginning in week, and in the cycle Can introduce the water in stratum during end.In some embodiments, the beginning in week can be the initial of cycle The initial 20-about 60% or the initial 25-in cycle about 40% in 10-about 80% or cycle, and week The end of term can be the remainder in cycle.

Referring now to Fig. 5, describe well array 500.Well array 500 includes the first well group 502 (horizontal line represents) and the second well group 504 (oblique line represents).Some realities in the inventive method Executing in scheme, the first well of method as above can include as the first well in well array 500 Organize multiple first wells of 502 descriptions, and the second well of method as above can include as well Multiple second wells that in array 500, second well group 504 describes.

Each well in first well group 502 can be away from the adjacent well horizontal range in the first well group 502 530.Horizontal range 530 can be about 5-5000 rice or about 7-1000 rice or about 10-500 Rice or about 20-250 rice or about 30-200 rice or about 50-150 rice or about 90-120 Rice or about 100 meters.Each well in first well group 502 can be away from the phase in the first well group 502 Offset well vertical dimension 532.Vertical dimension 532 can be about 5-5000 rice or about 7-1000 rice, Or about 10-500 rice or about 20-250 rice or about 30-200 rice or about 50-150 rice, Or about 90-120 rice or about 100 meters.

Each well in second well group 504 can be away from the adjacent well horizontal range in the second well group 504 536.Horizontal range 536 can be about 5-5000 rice or about 7-1000 rice or about 10-500 Rice or about 20-250 rice, or about 30-200 rice or about 50-150 rice, or about 90-120 Rice or about 100 meters.Each well in second well group 504 can be away from the phase in the second well group 504 Offset well vertical dimension 538.Vertical dimension 538 can be about 5-5000 rice or about 7-1000 rice, Or about 10-500 rice or about 20-250 rice or about 30-200 rice or about 50-150 rice, Or about 90-120 rice or about 100 meters.

Each well in first well group 502 can be away from the adjacent well distance 534 in the second well group 504. Each well in second well group 504 can be away from the adjacent well distance 534 in the first well group 502.Away from 5-5000 rice or about 7-1000 rice or about 10-500 rice or about 20-250 is can be about from 534 Rice or about 30-200 rice or about 50-150 rice or about 90-120 rice or about 100 meters.

Each well in first well group 502 can by four wells in the second well group 504 around.The Each well in two well groups 504 can by four wells in the first well group 502 around.

In some embodiments, well array 500 can have about 10-1000 well, such as first About 5-500 well in about 5-500 well in well group 502, and the second well group 504.

In some embodiments, what well array 500 can be considered to separate on plot hangs down First well group 502 and the top view of the second well group 504 of straight well.In some embodiments, Well array 500 can be considered first well group 502 He with the horizontal well separated in stratum The cross sectional side view on the stratum of the second well group 504.

For contributing to being more fully understood that the present invention, in terms of giving some of some embodiments Following example.Following example limit never in any form or define the scope of the present invention.

Embodiment

Carry out testing to determine that the aqueous formed with respect to combination copolymer and formation water is driven For fluid, use the Low-salinity aqueous displacement fluid viscosity to carrying in oil formation and bivalent cation The effect of exchange, described Low-salinity aqueous displacement fluid comprises polymer and is less than with having 5,000ppm and the TDS content of TDS content half less than formation water, and its MAR is stratum The 70-130% of the MAR of water.For Low-salinity aqueous displacement fluid and by combination copolymer with The aqueous displacement fluid that formation water is formed, measures the amount of polymers provided needed for identical viscosities.

With former at the temperature of 50 DEG C (corresponding to therefrom obtaining the formation temperature on the stratum of crude oil) Oil degradation sandstone core 4 weeks.Diffraction analysis shows that core material is 95% quartz, and residue 5% Comprise illite-terre verte, Kaolin and the green mud of illite-micaceous clay, potassium feldspar and trace Stone, anhydrite, calcite and pyrite.Then with having the synthesis stratum of composition shown in table 1 Water saturation core.

The low salinity water solution of preparation design, it has the TDS content of 2170ppm (relative to ground The TDS of layer water carries out 2.5 times of dilutions) and positive with monovalence equal to the bivalent cation of synthesis formation water The MAR of the bivalent cation of the MAR of ion and monovalent cation be (the low salinity water solution of design The 99% of the MAR of MAR=synthesis formation water).The composition of low salinity water solution is shown in table 1.

High salinity polymer solution is formed respectively by the low salinity water solution of synthesis formation water and design And Low-salinity polymer solution (LSP) (HSP).The polyacrylamide polymers that will be fully hydrolyzed FLOPAAM 3630S adds the low salinity water solution of extremely synthesis formation water and design and exists with preparation HSP solution and the LSP solution of 125cP viscosity it is respectively provided with at 50 DEG C.HSP solution comprises The polymer of 2483ppm and LSP solution comprise the polymer of 1761ppm.

Table 1

Then, with synthesis stratum water saturated core successively with the synthesis formation water of 30PV, then The design of the HSP solution of the low salinity water of the design of 30PV, then 80PV, then 30PV LSP solution processes.With the 3ml fraction collection respective effluent of these steps.Each step stream Go out the concentration of the sodium of thing fraction, potassium, calcium and magnesium cation by inductively coupled plasma element Analyze the peeling effect measuring water and polymer solution to determine injection.Fig. 6 and 7 gives Synthesis formation brine, the low salinity water of design, HSP solution and the outflow of LSP solution injected Na in thing⁺、Ca²⁺、Mg²⁺And K⁺Measurement concentration.HSP solution effluent and LSP solution stream Go out the Ca in thing²⁺And Mg²⁺Concentration slightly higher than at these solution, each injects HSP when starting With the concentration of these cationes in LSP solution, this is probably polymer to calcium and the affinity of magnesium Effect.But during injecting HSP and LSP solution, the calcium in effluent and magnesium density Fast quick-recovery extremely injects the baseline of these cation concns in solution.It is essential that LSP is molten Liquid does not demonstrate relative to HSP solution Ca²⁺And Mg²⁺Obvious stripping, this shows LSP The Low-salinity of solution can not cause calcium and the magnesium cation peeling off pronounced amount from core.

HSP solution is injected the viscosity of effluent and LSP solution injection effluent and is surveyed by flow graph Amount.Fig. 8 gives HSP solution effluent and the viscosity of LSP solution effluent.Each effluent Demonstrating that about 10% viscosity declines when injecting beginning, then viscosity maintains an equal level.It is apparent that LSP The viscosity of solution declines the viscosity decline being substantially similar to HSP solution, and this shows LSP solution Viscosity will not be significantly affected by the Low-salinity of LSP solution.This can close be coupled to LSP solution will not Substantial amounts of Ca is peeled off from core²⁺And Mg²⁺, this is attributable to the MAR of LSP solution equal to HSP The MAR of solution.

The present invention is well suited for realizing described and intrinsic purpose and advantage.Disclosed above Particular be merely to illustrate because the present invention can with different but to benefiting from herein For those skilled in the art of teaching, significantly equivalent way is adjusted and implements.Additionally, Described in following claims, it is not intended to details of construction or design herein shown.To the greatest extent Pipe describes described system and side in the way of " including " or " comprising " different component or step Method, but compositions and method can also be made up of different components and step or substantially by different Component or step composition.The openest numerical range with upper and lower bound, the most specifically Disclose all numerical value fallen in the range of this and all scopes comprised.Especially, herein Disclosed each numerical range (" from a to b " or be equivalent to the form of " a-b ") is interpreted as The each numerical range comprised in broader numerical.No matter when open only have specific under Limit, only there is the specific upper limit or there is the numerical range of the specific upper limit and certain lower limit, this scope May also include all numerical value of " approximation " certain lower limit and/or the specific upper limit.And, right is wanted The term asked has they simple generally implications, unless patentee makes determining of being expressly understood that Justice.Additionally, indefinite article used in claim is defined herein as it introduces element One or more.

Claims

1. for the method from load oil formation output oil, including:

Determine the bivalent cation of the water carrying oil formation and the mass action ratio of monovalent cation；

Thering is provided the aqueous displacement fluid of the polymer comprising water and ion live-wire, wherein said aqueous is driven For the water of fluid have the total dissolved solidss content of 200-5,000ppmw and its bivalent cation with The mass action of monovalent cation is than bivalent cation and the monovalent cation being the water carrying oil formation The 70-130% of mass action ratio；

2. the method for claim 1, further comprising the steps of:

Carrying in oil formation the oil viscosity determining described stratum at a temperature of in temperature range；

The aqueous displacement fluid of the 10-500% providing viscosity to be the oil viscosity carrying oil formation, wherein The viscosity of described aqueous displacement fluid determines at a temperature of the oil viscosity determining load oil formation.

3. the method for claim 2, the ionomer of wherein said aqueous displacement fluid is with described The water of aqueous displacement fluid is to be effectively increased the viscosity of the water of aqueous displacement fluid to carrying oil formation The amount mixing of the 10-500% of oil viscosity.

4. the method described in any one of claim 1-3, the polymer of wherein said ion live-wire is Aqueous dispersion polymers.

5. the method described in any one of claim 1-3, the polymer of wherein said ion live-wire is Water-soluble polymer.

6. the method described in any one of claim 1-5, the polymer choosing of wherein said ion live-wire From water-soluble polyacrylamide, water-soluble polyacrylate, the water-soluble polypropylene acyl of partial hydrolysis Amine and their mixture.

7. the method described in any one of claim 1-6, wherein carry oil formation water bivalence sun from Son is identified below with the MAR of monovalent cation: obtain the sample of water carrying oil formation, measurement available from Carry each bivalent cation material in the water of oil formation and the concentration of each monovalent cation material, and root Calculate available from the MAR of water carrying oil formation according to formula (I):

(I)MAR_fw=(C⁺ _(fw))²/(C²⁺ _(fw))

Wherein MAR_fwThe mass action of bivalent cation and monovalent cation for the water on described stratum Ratio, C⁺ _(fw)For the concentration summation of the monovalent cation material in the water on described stratum, and C²⁺ _(fw)For institute State the concentration summation of bivalent cation material in the water on stratum.

8. the method described in any one of claim 1-7, the water of wherein said aqueous displacement fluid by The open water supply of the TDS content with 200-5,000ppm provides.

9. the method described in any one of claim 1-7, the water of wherein said aqueous displacement fluid by Having higher than 10, the saline water source of the TDS content of 000ppm provides, and wherein processes described saline Water source is to regulate the TDS content at described saline water source in the range of 200-5,000ppm.

10. the method described in any one of claim 1-7, the water of wherein said aqueous displacement fluid Thered is provided by the water source with the TDS content less than 500ppm, wherein process described water source to adjust Save the TDS content at described water source in the range of 500-5,000ppm.

Method described in 11. any one of claim 1-10, the water of wherein said aqueous displacement fluid Bivalent cation and one by its bivalent cation Yu the water that MAR is described stratum of monovalent cation The water source of the 70-130% of the MAR of valency cation provides, the water of wherein said aqueous displacement fluid MAR calculate according to formula (II):

(II)MAR_adf=(C⁺ _(adf))²/(C²⁺ _(adf))

Wherein MAR_adfBivalent cation and monovalent cation for the water of described aqueous displacement fluid Mass action ratio, C⁺ _(adf)Concentration for the monovalent cation material in the water of described aqueous displacement fluid Summation, and C²⁺ _(adf)Concentration for the bivalent cation material in the water of described aqueous displacement fluid is total With.

Method described in 12. any one of claim 1-10, the water of wherein said aqueous displacement fluid By the MAR of its bivalent cation and monovalent cation less than the water on described stratum bivalent cation with The MAR of monovalent cation 70% or higher than described stratum water bivalent cation and monovalence sun from The water source of the 130% of the MAR of son provides, and regulates bivalent cation and the monovalence sun at described water source The bivalent cation of the MAR of the ion extremely water on described stratum is with the MAR's of monovalent cation The scope of 70-130%, the MAR of the water of wherein said aqueous displacement fluid calculates according to formula (II):

(II)MAR_adf=(C⁺ _(adf))²/(C²⁺ _(adf))

Method described in 13. any one of claim 1-12, also includes together with carrying the oil of oil formation Output carries the water of oil formation and separates the oil of output and the water of output.