CN105247165A - Process for enhancing oil recovery from an oil-bearing formation - Google Patents
Process for enhancing oil recovery from an oil-bearing formation Download PDFInfo
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- CN105247165A CN105247165A CN201480030946.0A CN201480030946A CN105247165A CN 105247165 A CN105247165 A CN 105247165A CN 201480030946 A CN201480030946 A CN 201480030946A CN 105247165 A CN105247165 A CN 105247165A
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/20—Displacing by water
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/162—Injecting fluid from longitudinally spaced locations in injection well
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Abstract
A process for recovering oil from an oil-bearing formation is provided. A first oil recovery fluid is introduced into a formation through a first well for a first time period and oil is produced from a second well. A second oil recovery fluid different from the first oil recovery fluid is introduced into the formation through the second well for a second time period after the first time period, and oil is produced from a third well, where the second well is located on a fluid flow path extending between the first and third well.
Description
Technical field
The present invention relates to the method for improving the recovery ratio of recovering the oil from oil-bearing layer.
Background technology
In the process of recovering the oil from underground reservoir, a part for the oil in stratum of only being gathered by the primary oil recovery method adopting use natural stratum pressure to produce oil.The part oil can not produced from stratum by adopting primary oil recovery method by improve or the oil recovery method (EOR) that improves and being produced.
In secondary oil recovery process, water or salt solution are injected into and extend in the Injection Well of oil-bearing layer after primary oil recovery process terminates.Water or salt solution make the oil flow in stratum, are advanced to the producing well separated by a distance with Injection Well by the oil of flowing from Injection Well.Oil and the formation water of flowing and be produced in producing well together with being injected in stratum water.
Although secondary oil recovery process effectively extraction can remain the some parts of oil in the earth formation after primary oil recovery process terminates, often a large amount of parts of residual oil can be remained in the earth formation.Oil can be arrested in the hole of formation rock, or oil can adhere to stratum rock surface on instead of be advanced to stratum by the water of injection.At the water be injected into through after stratum, residual oil can blocked (if only use primary oil recovery process and secondary oil recovery process to carry out recovery of oil from stratum, so this will reduce the oil mass of gathering from stratum potentially greatly) in the earth formation.
A part for residual oil in stratum on some positions can after secondary oil recovery water drive, by oil recovery formulation (it is different from and is injected into water in stratum or salt solution in secondary oil recovery water drive) is injected stratum and is produced, this process is referred to as tertiary oil recovery process.Tertiary oil recovery preparation makes oil circulation by such as under type: such as by discharging the oil be arrested in the hole of formation rock, or by changing the oily adhesiveness adhered on the rock surface on stratum, or by the interfacial tension between the residual oil in reduction stratum and water, or by changing the physical characteristic (e.g., viscosity) of residual oil.The example of this tertiary oil recovery preparation comprise LIS water, water soluble polymeric agents, alkali, surfactant and polymer preparation, oil-dissolving solvent (as, dimethyl ether) and oil-soluble gas (e.g., carbon dioxide and low-molecular-weight hydrocarbon).
Secondary oil recovery process and tertiary oil recovery process is performed by adopting traditional Injection Well-producing well configuration.Select some traditional Injection Wells for secondary oil recovery process and tertiary oil recovery process-producing wells configuration, the oil that the water that is injected into or oil recovery preparation are promoted in stratum arrives producing well from Injection Well through stratum.The large-scale array of this Injection Well-producing well can be used for producing oil from single stratum.Such as, 10 to 1000 Injection Well-producing wells are in the direct flow path be disposed in from Injection Well to producing well, and they can be used to produce oil from single stratum.
But, when using the configuration of some traditional Injection Well-producing well, application tertiary oil recovery process be have circumscribed.In some traditional Injection Well such as in application scenario, coastal waters-producing well configuration, because the disbursement for drilling well is high, Injection Well and producing well are arranged to a good distance off distance, as 1km or farther.In secondary oil recovery process, make oil flow, drive oil in a certain pattern or Linear Driving form through stratum.Distance between Injection Well and producing well can make tertiary oil recovery process technically and unrealistic economically, reason is, to be made by secondary oil recovery process oil circulation arrive in producing well after this process waiting as long for, make oil circulation arrive the stand-by period that in producing well, this process entails is long by tertiary oil recovery preparation.In addition, some in these Injection Wells-producing well configuration are formed together with peripheral injector, water is injected into below the oil/water contact position in stratum by peripheral injector, wherein, the water be injected into can limit or stop tertiary oil recovery preparation to contact oil, and this will cause the loss of tertiary oil recovery preparation.
Need a kind of tertiary oil recovery process of improvement to carry out recovering residual oil from oil-bearing layer, wherein, Injection Well and producing well are arranged to distance relatively far apart.
Summary of the invention
The present invention relates to the method for recovery of oil from oil-bearing layer, the method comprises the following steps:
In the first period, by the first well extended in stratum, the first oil recovery fluid is injected oil-bearing layer, produce fuel-displaced from stratum by the second well extended in stratum;
In the second period, by the first well, the first oil recovery fluid is injected stratum, by the second well, the second oil recovery formulation is injected stratum, produce fuel-displaced from stratum by the Mitsui extended in stratum, wherein, the fluid flow path of the second well location in stratum is between the first well and the second well; Wherein, the second oil recovery fluid is different from the first oil recovery fluid; Wherein, the second period was after the first period of time, the second period when produced the mixture comprising oil and the first oil recovery fluid at the beginning from stratum by the second well just.
Other advantages of the present disclosure and other features partly will be explained in declaratives below, those of ordinary skill in the art can obviously find out these advantages and feature after by the content below research, or can find out these advantages and feature from practice of the present disclosure.Can be familiar with and understand advantage of the present disclosure, they are specifically noted in the appended claims.
It should be understood that the disclosure can have other or different embodiments, its some details various obvious in can there is improved form, all these improved forms do not depart from the scope of the present disclosure.Therefore, drawing and description should be considered to be illustrative in essence and nonrestrictive.
Accompanying drawing explanation
Accompanying drawing only by way of example and unrestriced mode shows one or more embodiments according to this instruction.In the accompanying drawings, similar Reference numeral represents same or analogous element.
Fig. 1 illustrates in the petroleum production system with vertical layout well, the step that method of the present invention performed in the first period of implementation process.
Fig. 2 illustrates in the petroleum production system with well (it has the part of horizontal arrangement), the step that method of the present invention performed in the second period of implementation process.
Fig. 3 is the sketch for the raw petroliferous well arrangement mode of method according to the present invention.
Fig. 4 illustrates in the petroleum production system with vertical layout well, the step that method of the present invention performed in the second period of implementation process.
Fig. 5 illustrates in the petroleum production system with well (it has the part of horizontal arrangement), the step that method of the present invention performed in the second period of implementation process.
Fig. 6 illustrates in the petroleum production system with vertical layout well, the step that method of the present invention performed in the second period of implementation process.
Fig. 7 illustrates in the petroleum production system with well (it has the part of horizontal arrangement), the step that method of the present invention performed in the second period of implementation process.
Fig. 8 illustrates in the petroleum production system with vertical layout well, the step that method of the present invention performed in the second period of implementation process; Wherein, oil is produced from the first well and Mitsui.
Fig. 9 illustrates in the petroleum production system with vertical layout well, the step that method of the present invention performed in the second period of implementation process.
Figure 10 illustrates in the petroleum production system with well (it has the part of horizontal arrangement), the step that method of the present invention performed in the second period of implementation process.
Detailed description of the invention
The present invention relates to the oil recovery method of improvement, in this oil recovery method, first in the first period, by the oil recovery formulation of improvement, (the first oil recovery fluid---after being injected in stratum by the first well, the oil recovery formulation (the second oil recovery fluid) improved is injected oil-bearing layer by the second well passed through between the first well and Mitsui in the second period.Second oil recovery fluid is different from the first oil recovery fluid.Produce fuel-displaced from the second well at the time durations at least partially of the first period, at the time durations at least partially of the second period, alternatively at the time durations at least partially of the first period, produce fuel-displaced from Mitsui.Second period when produced the mixture comprising oil and the first oil recovery fluid at the beginning from stratum by the second well just.When the first well and the spaced great distances of Mitsui, injecting the second oil recovery fluid by the second well after the first period of time can allow the second oil recovery fluid that the residual oil for gathering is flowed, and this residual oil is failed due to the effect of the first oil recovery fluid and flows.Relative to for producing this oil (such as from Mitsui, if inject the second oil recovery fluid by means of only the first well, from Mitsui, produce this oil by requiring) period compare, can greatly reduce for producing the period becoming the oil of flowing owing to injecting the second oil recovery fluid by the second well from Mitsui, such as, for the production of this period can reduce the several years to many decades.When improving oily output below the oil/water contact position being noted to by water in stratum when using peripheral water jet, by the second well but not the first initial Injection Well by second oil recovery fluid inject stratum, to the risk of loss second oil recovery fluid be reduced, and the residual oil flowing of gathering can not be used in.
Referring now to Fig. 1, show the first well 101, second well 103 and Mitsui 105 from surface 107, enter oil-bearing layer 111 through overlying strata 109.If oil-bearing layer 111 is positioned at coastal waters, so surface 107 can be positioned at the platform on ocean 113; Or if oil-bearing layer 111 is positioned at land, so surface 107 can be earth surface (not shown).
First well 101 can be the conventional well for fluid being injected oil-bearing layer; Second well 103 can be for fluid being injected oil-bearing layer and being used for producing the conventional well comprising oily fluid from stratum; Mitsui 105 can be the conventional well for producing the fluid comprising oil from oil-bearing layer.In some embodiments of method of the present invention, the first well 101, except can being the conventional well for fluid being injected oil-bearing layer, can also be the conventional well for producing the fluid comprising oil from stratum.The fluid flow path of the second well 103 in stratum is between the first well 101 and Mitsui 105.In an embodiment of method of the present invention, the method can be performed in coastal waters, second well 103 can be moved to the sidetracked hole on the correct position between the first well 101 and Mitsui 105, wherein, second sidetracked hole 103 is positioned at stratum 111, and is in the fluid flow path between the first well and Mitsui.
As shown in Figure 1, for the surface of ocean 113 or earth surface, first well 101, Mitsui 103 and Mitsui 105 can be wells that is vertically main or that be positioned laterally in stratum, wherein, each in the well 101,103 and 105 of vertical or located lateral is arranged to interval certain level distance each other in stratum 111.In another embodiment, as shown in Figure 2, the part 205 of the part 201 of Injection Well 101, the part 203 of intermediate wells 103 and producing well 105 can relative to the surface of ocean (not shown) or earth surface 114 be approximate horizontal is positioned in stratum, wherein, each in the part 201,203 and 205 of the approximate horizontal location of well 101,103 and 105 is arranged to the certain vertical distance in interval each other in stratum.
Referring now to Fig. 3, show the array 300 of well.Array 300 comprises the first well group 301 (representing with vertical line), the second well group 303 (illustrating with horizon) and the 3rd well group 305 (illustrating with diagonal).Above-mentioned first well can comprise multiple first well, and it is shown as the first well group 301 in array 300; Above-mentioned second well can comprise multiple second well, and it is shown as the second well group 303 in array 300; Above-mentioned Mitsui can comprise multiple Mitsui, and it is shown as the 3rd well group 305 in array 300.
In certain embodiments, the array 300 of well can be looked at as top view, the first well group 301, second well group 305 and the 3rd well group 307 be separate on plot band by the well vertically arranged.In certain embodiments, the array 300 of well can be looked at as the cross-sectional side view on stratum, illustrates that the horizontal arrangement part of the horizontal arrangement part of the second well of the horizontal arrangement part of the first well of the first well group 301, the second well group 302 and the Mitsui of the 3rd well group 305 is spaced apart in stratum respectively.
Each first well in first well group 301 can with the first adjacent well spacing distance 311 in the first well group, wherein this distance 311 can be about 100 meters to about ten thousand metres, or be about 250 meters to about 5000m or be about 500 meters to about 1000 meters.Each first well in first well group 301 can with the first adjacent well spacing distance 313 in the first well group.This distance 313 can be about 5 meters to about ten thousand metres or be about 10 meters to about 2500 meters or be about 15 meters to about 1000 meters.
Each second well in second well group 303 can with the second adjacent well standoff distance 315 in the second well group.This distance 315 can be about 100 meters to about ten thousand metres or for about 250 meters of rice are to about 5000m, or be about 500 meters to about 1000 meters.Each second well in second well group 303 can with the second adjacent well spacing distance 317 in the second well group.Distance 317 can be about 5 meters of extremely about ten thousand metres, or is about 10 meters to about 2500 meters, or is about 15 meters to about 1000 meters.
Each Mitsui in 3rd well group 305 can with the adjacent Mitsui spacing distance 319 in the 3rd well group.Distance 319 can be about 100 meters of extremely about ten thousand metres, or is about 250 meters of extremely about 5000m, or is about 500 meters to about 1000 meters.Each Mitsui in 3rd well group 305 and the adjacent producing well spacing distance 321 in the 3rd well group.Distance 321 can be about 5 meters to about ten thousand metres, or be about 10 meters to about 2500 meters or be about 15 meters to about 1000 meters.
Each first well in first well group 301 can with the second adjacent well spacing distance 323 in the second well group 303.Each second well in second well group 303 can with the first adjacent well spacing distance 323 in the first well group 301.Distance 323 can be about 3 meters to about 5000m, or be about 5 meters to about 2500 meters or be about 10 meters to about 1000 meters, wherein, can be less than apart from 323 apart from 311 and/or apart from 313.
Each second well in second well group 303 can with the adjacent Mitsui spacing distance 325 in the 3rd well group 305.Each Mitsui in 3rd well group 305 can with the second adjacent well spacing distance 325 in the second well group 303.Distance 325 can be about 3 meters to about 5000m or be about 5 meters to about 2500 meters or be about 10 meters to about 1000 meters.
Each first well in first well group 301 can with the nearest Mitsui spacing distance 327 in the 3rd well group 305.Each Mitsui in 3rd well group 305 can with the first nearest well spacing distance 327 in the first well group 301.Distance 327 can be about 4 meters to about 7500 meters or for about 5 meters to about 5000m or be about 10 meters to about 2500 meters, wherein, is greater than apart from 323 apart from 327.
In certain embodiments, the array 300 of well can have 15 to 1500 mouthfuls of wells, such as, has 5 to 500 mouthful of first well in the first well group 301, has 5 to 500 mouthful of second well in the second well group 303, have 5 to 500 mouthfuls of Mitsuis in the 3rd well group 305.
Oil-bearing layer can comprise porous matrix material, You Heshui.After oil-bearing layer is included in introducing first oil recovery fluid, and after the second oil recovery fluid being introduced stratum after following closely the first oil recovery fluid introducing stratum, be separated and the oil produced from stratum from stratum.Stratum preferably comprises a large amount of in-place oil, by using the first oil recovery fluid and the second oil recovery fluid and making described crude oil flow and produce the oil of this flowing subsequently, a big chunk crude oil so just can gathered from stratum in this in-place oil.
Oil-bearing layer also can comprise water, and this water can be arranged in the hole of porous matrix material.Water in stratum can be connate water.
The porous matrix material on stratum can be made up of one or more of porous matrix material, and these porous matrix material are selected from the group be made up of the combination of both porous mineral matrix, porous rock matrix and porous mineral matrix and porous rock matrix.The rock on stratum and/or mineral porous matrix material can be made up of sandstone, shale and/or carbonate, and carbonate is selected from dolomite, limestone and their mixture, and wherein limestone can be crystallite or crystalline limestone.The permeability on stratum can be 0.0001 to 15 darcy, or can be 0.001 to 1 darcy.
Oil in oil-bearing layer can be arranged in the hole of the porous matrix material on stratum.Oil in oil-bearing layer such as by capillary force, by oil and hole surface interaction, by oil viscosity or can keep motionless in the hole in the porous matrix material on stratum by the interfacial tension between the oil in stratum and water.
Oil-bearing layer can be easily produce oil by the first oil recovery fluid and the second oil recovery fluid are injected stratum, and easily subsequently produces from stratum and the stratum of recovery of oil.The first oil recovery fluid and the second oil recovery fluid is used from stratum, to extract core plug as injectant out successively, the suitability of stratum for oil recovery can be determined by performing traditional rock core flowing research to this core plug, wherein, soak in core plug to have and come from oil in stratum and connate water or water (its salinity adapts to the stratum connate water salinity under the similar initial water saturation ratio before injection first and second oil recovery fluid).
Referring again to Fig. 1, in the method for the invention, in the first period, such as adopt and by the first well 101, first oil recovery fluid injected the mode on stratum and the first oil recovery fluid introduced oil-bearing layer 111, above-mentioned injection mode is, is delivered in stratum by the first oil recovery fluid pump by the first well 101.After the primary oil recovery process of recovery of oil from stratum terminates, as, cause less oil due to the natural pressure on stratum or do not have after other oil can gather from stratum, described first period can be started and the first oil recovery fluid is injected the injection process on stratum 111.
Pressure when first oil recovery fluid is introduced in stratum 111 by the first well 101 can instantaneous pressure in the earth formation to stratum fracture pressure or exceed stratum fracture pressure pressure scope in change.Pressure when first oil recovery fluid is injected into stratum can change in the scope of 20% to 95% or 40% to 90% of the fracture pressure on stratum.Alternatively, the first oil recovery fluid is injected into stratum under the minimum pressure for formation fracture pressure, wherein, can inject the first oil recovery fluid under formation breakdown condition.
Change within the scope of be introduced into the pore volume of volume between the first well 101 and Mitsui 105 of the first oil recovery fluid in stratum 111 by the first well 101 0.5 to 20 times, or change within the scope of 1 to 10 times of pore volume between the first well and Mitsui, or change within the scope of 2 to 5 times of pore volume between the first well and Mitsui, wherein, term " pore volume between the first well and Mitsui " represents the formation volume that the first oil recovery fluid between the first well 101 and Mitsui 105 skims over.Pore volume between first well and Mitsui easily can be determined by the known method of those skilled in the art, such as, by analog study or by injecting stratum 111 from the first well 101 to Mitsui 105 by the water containing tracker in it.
First oil recovery fluid can be water or salt solution.First oil recovery fluid can be such as be used in water in the water flood in traditional secondary oil recovery process or salt solution, and wherein, the injection of the first oil recovery fluid can be the water flood for improving the oil recovery of recovering the oil from stratum.The water or salt solution that are used as the first oil recovery fluid can be provided from seawater, brackish water, aquifer, lake, river or the water produced from stratum.Can containing being maybe conditioned containing the sulfate ion (SO being less than 100mg/l as the water of the first oil recovery fluid or salt solution
4 2-) to suppress formation acidizing by sulfuric acid consumption bacterium.By the conventional method for removing sulfate ion from water, such as, by nanofiltration, by counter-infiltration, by just to permeate or by ion-exchange, regulate the first oil recovery fluid water or salt solution to make it contain to be less than the sulfate of 100mg/l.Can containing total dissolved solidss (TDS) content that maybe can be adjusted to containing being at least 200/1000000ths (ppm) as the water of the first oil recovery fluid or salt solution, to avoid the stratum instability caused because clay expands in stratum.By adding in fresh water by sodium chloride or calcium chloride, the fresh water that TDS content can be less than 200ppm is adjusted to the TDS content containing being at least 200ppm.Salt solution as the first oil recovery fluid preferably contains the TDS content that maybe can be adjusted to containing being less than 50000ppm.By traditional desalination method, such as, desalted, nanofiltration, counter-infiltration, just to permeate and ion-exchange by heating, salt solution TDS content being greater than 50000ppm is adjusted to the TDS content containing being less than 50000ppm.
When first oil recovery fluid is introduced in stratum 111 during the first period, the first oil recovery fluid spreads in stratum as indicated by the arrow 115 like that.Once the first oil recovery fluid be introduced stratum 111, first oil recovery fluid with regard to the oil in contact stratum during the first period, make the flowing at least partially of the oil be touched, promote entering in the second well 103 through stratum at least partially of the oil 117 of flowing.Then, to be produced in the oil 117 of described flowing at least partially from stratum by the second well 103.By being introduced in stratum by the first oil recovery fluid, the part 119 that can promote the oil flowed enters in Mitsui through stratum, thus during the first period, produce oil by Mitsui 119 flowing part.
With reference to Fig. 2, when well water level land is arranged in the earth formation, the first oil recovery fluid is introduced in stratum by the horizontal arrangement part 201 of the first well 101, and the first oil recovery fluid can spread in stratum 111 as indicated by arrows 215 like that.Oil in first oil recovery fluid contact stratum, makes the flowing at least partially of the oil be touched, being pushed to the oil 217 of flowing downwards at least partially in the horizontal arrangement part 203 of the second well 103.Then from stratum, the oil 217 of flowing is produced at least partially by the second well 103.By being introduced in stratum by the first oil recovery fluid, a part 219 for the oil of flowing also can be pushed downward in the horizontal arrangement part 205 of Mitsui 105.During the first period, the horizontal arrangement part 205 by Mitsui 105 produces the flowing part of fuel-displaced 219.
Referring now to Fig. 1 and 2, elongated segment when first, until a part for the first oil recovery fluid is produced together with oil by the second well 103 the earliest from stratum.First fluid recovered is produced with mixture form by the second well 103, and this mixture is made up of oil, formation water and the first oil recovery fluid.First period can extend, until the first oil recovery fluid in the mixture (it comprises oil, formation water and the first oil recovery fluid) be produced by the second well 103 and the gross weight of formation water and the ratio of weight of oil are at least 1:1 the earliest or are at least 2:1.
Referring now to Figure 4 and 5, after the first period, the second oil recovery fluid is injected in stratum 111 by the second well 103, produces fuel-displaced in the second period by Mitsui 105 from stratum.During the portion of time of the second period or during whole second period, the first oil recovery fluid can be injected in the first well 101.
Second period started after the first period of time.Second period can the first period once at the end of start immediately, or can to start a period of time after the first period terminated.Second period just started in time producing by the second well 103 mixture comprising oil and the first oil recovery fluid at the beginning.Second period the earliest can in time producing the mixture comprising oil, formation water and the first oil recovery formulation, and wherein, the first oil recovery fluid in this mixture and the gross weight of formation water and the ratio of weight of oil are at least 1:1 or are at least 2:1.Second period can be terminated when the process on the second oil recovery fluid injection stratum 111 being stopped by the second well 103.
Second oil recovery fluid can be introduced in stratum by the first oil recovery fluid, after oil and the first oil recovery fluid contact in stratum, effectively makes the fluid of residual residual oil flowing in the earth formation.Second oil recovery fluid is except can effectively make by being introduced in stratum and become flowing and the oil flow of producing and except being produced, can also effectively make abundant residues oil flow and be produced by the first oil recovery fluid.After the first oil recovery fluid flows into stratum, by discharging the residual oil be arrested in the hole of formation rock, or adhere to adhesiveness on formation rock surface by changing residual oil, or by reducing the interfacial tension between the water in residual oil and stratum, or by change residual oil physical characteristic (as, viscosity), thus the second oil recovery fluid can make residual oil flow.Second oil recovery fluid is different from the first oil recovery fluid, it can be selected from the group be made up of the aqueous solution of the aqueous solution of Low-salinity water-based fluid (its ionic strength is up to 0.15M, and TDS content is 200ppm to 10000ppm), the aqueous solution of surfactant or the composition of kinds of surface activating agent, alkali, surfactant and polymer preparation, water-soluble polymer, dimethyl ether and their mixture.
Second oil recovery fluid can be the Low-salinity water-based fluid that ionic strength is up to that 0.15M, TDS content is 200ppm to 10000ppm.The TDS content of this Low-salinity water-based fluid can be 500ppm to 7000ppm, or 1000ppm to 5000ppm, or 1500ppm to 4500ppm.The ionic strength of Low-salinity water-based fluid is up to 0.1M or is up to 0.05M or is up to 0.01M, and ionic strength can be 0.01M to 0.15M, or 0.02M to 0.125M, or 0.03M to 0.1M.The term " ionic strength " used in literary composition is limited by equation below:
Wherein, I is ionic strength, and c is the molar concentration of ion i, and z is the chemical valence of ion i, and n is the amount of ions in surveyed solution.
The ionic strength of Low-salinity water-based fluid can be less than the ionic strength of the connate water existed in oil-bearing layer, and/or, the polyvalent cation concentration of Low-salinity water-based fluid is less than the polyvalent cation concentration of the connate water existed in oil-bearing layer, and/or the divalent cation concentration of Low-salinity water-based fluid is less than the divalent cation concentration of the connate water existed in oil-bearing layer.The ionic strength of Low-salinity water-based fluid can be less than 1 with the ratio of the ionic strength of connate water, maybe can be less than 0.9, maybe can be less than 0.5, maybe can be less than 0.1, or can be for 0.01 to 1 (but not comprising 1), or can be 0.05 to 0.9, or can be 0.1 to 0.8.The concentration of multivalent cations of Low-salinity water-based fluid can be less than 1 with the ratio of the concentration of multivalent cations of connate water, or can be less than 0.9, maybe can be less than 0.5, maybe can be less than 0.1, or can be for 0.01 to 1 (but not comprising 1), or can be 0.05 to 0.9, or can be 0.1 to 0.8.The divalent ion content of Low-salinity water-based fluid can be less than 1 with the ratio of the divalent ion content of connate water, or is less than 0.9, or is less than 0.5, or is less than 0.1, or is 0.01 to 1 (but not comprising 1), or is 0.05 to 0.9, or is 0.1 to 0.8.
Low-salinity water-based fluid can have relatively low concentration of multivalent cations and/or relatively low divalent ion content.The polyvalent cation concentration of Low-salinity water-based fluid reaches as high as 200ppm, or reach as high as 100ppm, or reach as high as 75ppm, or reach as high as 50ppm, or reach as high as 25ppm, or can be 1ppm to 200ppm, or can be 2ppm to 100ppm, or can be 3ppm to 75ppm, or can be 4ppm to 50ppm, or can be 5ppm to 25ppm.The divalent cation concentration of Low-salinity water-based fluid reaches as high as 150ppm, or reach as high as 100ppm, or reach as high as 75ppm, or reach as high as 50ppm, or reach as high as 25ppm, or can be 1ppm to 100ppm, or can be 2ppm to 75ppm, or can be 3ppm to 50ppm, or can be 4ppm to 25ppm, or can be 5ppm to 20ppm.
Low-salinity water-based fluid can be provided from natural resource, or be greater than the water source of 10000ppm to provide Low-salinity water-based fluid by process TDS content; Or, if need to use TDS content to be equal to or less than the Low-salinity water-based fluid of 5000ppm, be greater than the water source of 5000ppm to produce water-based fluid by process TDS content, thus Low-salinity water-based fluid be provided.Water-based fluid can be provided from natural resource (e.g., comprising the aquifer of the water containing 200ppm to 10000ppm total dissolved solidss, lake or river).
The saline source of 10000ppm is greater than to produce water-based fluid by process TDS content, thus can provide Low-salinity water-based fluid or its at least partially, this system also can comprise the saline source that TDS content is greater than 10000ppm and the saline source being greater than 10000ppm for the treatment of TDS content to produce the mechanism of Low-salinity water-based fluid.The TDS content of saline source can be at least 10000ppm, or is at least 15000ppm, or is at least 17500ppm, or be at least 20000ppm, or be at least 25000ppm, or be at least 30000ppm, or be at least 40000ppm, or be at least 50000ppm, or be 10000ppm to 250000ppm, or be 15000ppm to 200000ppm, or be 17500ppm to 150000ppm, or be 20000ppm to 100000ppm, or be 25000ppm to 50000ppm.Saline source to be treated can be selected from by the water in aquifer, seawater, brackish water, the water produced from oil-bearing layer and the group that forms of their mixture.Can according to traditional desalination method process salt solution to produce the Low-salinity water-based fluid being used as the second oil recovery fluid.
Alternatively, the second oil recovery fluid can be the aqueous solution containing one or more of surfactant.Surfactant can be after the first oil recovery fluid enters stratum, effectively reduces the interfacial tension between water and residual residual oil in the earth formation, thus residual oil is flowed with any surfactant produced from stratum.Surfactant can be anion surfactant.Anion surfactant can be containing the compound of the compound of sulfonate, containing sulfate, carboxylate complex, phosphate complex or their mixture.Anion surfactant can be alpha-alkene sulfonate compound, inner olefin sulfonic acid salt composite, branch-alkylbenzene sulfonate compound, propylene oxide sulphate complex, ethylene oxide sulphate complex, oxypropylene-oxyethylene sulphate complex or their mixture.Anion surfactant can contain 12 to 28 carbon atoms or 12 to 20 carbon atoms.Surfactant in second oil recovery fluid can comprise inner olefin sulfonic acid salt composite (it contains 15 to 18 carbon atoms) or propylene oxide sulphate complex (it contains 12 to 15 carbon atoms), or their mixture; Wherein, the volume ratio of the propylene oxide sulfate contained in this mixture and inner olefin sulfonic acid salt composite (internalolefinsulfonatecompound) is 1:1 to 10:1.
The aqueous surfactant solution of the second oil recovery fluid can contain a certain amount of surfactant, effectively to reduce the interfacial tension between residual oil in stratum and water, thus residual oil can be made to flow to produce from stratum.Can be surfactant or the surface activator composition of 0.05% to 5% containing percentage by weight in the aqueous surfactant solution of the second oil recovery fluid, can be maybe surfactant or the surface activator composition of 0.1% to 3% containing percentage by weight.
The aqueous surfactant solution of the second oil recovery fluid also can contain cosolvent, wherein, this cosolvent can be that low-molecular-weight alcohol (including, but not limited to methyl alcohol, ethanol and isopropyl alcohol, isobutanol, sec-butyl alcohol, n-butanol, the tert-butyl alcohol) or glycol are (including, but not limited to ethylene glycol, 1, ammediol, 1,2-PD, butyl, triethylene glycol monobutyl ester) or sulfosuccinate (including, but not limited to sulfosuccinic acid dihexyl sodium).Cosolvent can be used in the aqueous surfactant solution of the second oil recovery fluid, prevents from forming viscous emulsion for contributing to.If there is cosolvent, cosolvent can account for 100ppm to 50000ppm or the 500ppm to 5000ppm of the aqueous surfactant solution of the second oil recovery fluid.Cosolvent can not be present in the aqueous surfactant solution of the second oil recovery fluid.
Alternatively, the second oil recovery fluid can be the water resulting mixture containing polymer.The aqueous polymers mixture of the second oil recovery fluid can be produced or be adjusted to and make its viscosity number magnitude and the residual oil in the stratum viscosity number magnitude under formation temperature conditions identical, thus, second oil recovery fluid can make residual oil flow, drive residual oil to pass stratum to produce from stratum, immerse oil in minimum in the second oil recovery fluid and/or the second oil recovery fluid immersion oil minimum.Aqueous polymers mixture can comprise the polymer in the group being selected from and being made up of following material: polyacrylamide; Partially hydrolyzed polyacrylamide (PHPA); Polyacrylate; Alkenyl copolymers; Biopolymer; Carboxymethyl cellulose (carboxymethylcelloluses); Polyvinyl alcohol; Polystyrene Sulronate; Polyvinylpyrrolidone; AMPS (2-acrylamide-2-methylpro panesulfonic acid); Acrylamide, acrylic acid, AMPS and n-vinyl pyrrolidone are with the copolymer of any ratio; And the composition of these materials aforementioned.The example of alkenyl copolymers comprises the copolymer of the copolymer of the copolymer of acrylic acid and acrylamide, acrylic acid and laruyl alcohol acrylate, laruyl alcohol acrylate and acrylamide.The example of biopolymer comprises xanthans, closes magnificent bean gum and scleroglucan.
Amount of polymers in the aqueous polymers mixture of the second oil recovery fluid should be enough to make the viscosity of the second oil recovery fluid to be enough to drive the residual oil that can flow through oil-bearing layer, and making the second oil recovery fluid immerse the minimum and residual oil that is that can flow described in making of the described residual oil that can flow, to immerse the second oil recovery fluid minimum.Amount of polymers in the aqueous polymers mixture of the second oil recovery fluid should be enough to make the second oil recovery fluid dynamic viscosity order of magnitude to be at the formation temperature equal to or greater than the residual oil dynamic viscosity order of magnitude at the formation temperature in (not too recommending) oil-bearing layer, thus the second oil recovery fluid can advance movable residual oil through stratum.Amount of polymers in the aqueous polymers mixture of the second oil recovery fluid should be enough to make the dynamic viscosity of the second oil recovery fluid under 25 DEG C or temperature within the scope of formation temperature, be at least 1mPas (1cP) or be at least 10mPas (10cP) or be at least 100mPas (100cP) or be at least 1000mPas (1000cP).Polymer concentration in the aqueous mixture of the second oil recovery fluid can be 250ppm to 10000ppm, or can be 500ppm to 5000ppm, or can be 1000 to 2000ppm.
The mean molecule quantity of the polymer in aqueous polymers mixture should be enough to provide enough viscosity to the second oil recovery fluid, to drive movable residual oil through stratum.The mean molecule quantity of polymer is at least 10000 dalton, or is at least 50000 dalton, or is at least 100000 dalton.The mean molecule quantity of polymer is 10000 to 30000000 dalton, or is 100000 to 15000000 dalton.
Alternatively, the second oil recovery fluid can be alkali-surfactant-polymer (ASP) preparation.ASP preparation can be containing one or more of above-mentioned surfactant, the aqueous solution containing one or more of above-mentioned polymer and containing alkali.Alkali in second oil recovery fluid ASP preparation can be effectively to interact with the residual oil in stratum, to form any alkali of the fatty acid ester of the interfacial tension that can effectively reduce between residual oil in stratum and water.Second oil recovery fluid ASP preparation can comprise one or more of alkali compound.This one or more of alkali compound can be selected from the group be made up of following ingredients: lithium hydroxide, NaOH, potassium hydroxide, lithium carbonate, sodium carbonate, potash, lithium bicarbonate, sodium acid carbonate, saleratus, lithium metasilicate, silicate of soda, potassium silicate, lithium phosphate, sodium phosphate, potassium phosphate and their mixture.
Second oil recovery fluid ASP preparation can contain a certain amount of above-mentioned surfactant, a certain amount of above-mentioned polymer and a certain amount of alkali, described a certain amount of alkali can interact to form soap with the residual oil in stratum effectively, this soap effectively reduces the interfacial tension between residual oil in stratum and water, thus residual oil is flowed to produce from stratum.Second oil recovery fluid can be the alkali of 0.001% to 5% containing percentage by weight, or percentage by weight is the alkali of 0.005% to 1%, or percentage by weight is the alkali of 0.01% to 0.5%.
Alternatively, the second oil recovery fluid can comprise ether, is preferably dimethyl ether (DME) or diethyl ether (DEE).Ether in second oil recovery fluid should water soluble, oil-soluble, and wherein, by introducing in stratum by the second oil recovery fluid, this ether can enter in the residual oil in stratum through formation water and/or the first oil recovery fluid; Owing to reducing remaining oil viscosity at ether in time contacting residual oil, thus ether can make residual oil flow.Preferably, the second oil recovery fluid is dimethyl ether preparation.Dimethyl ether preparation can comprise dimethyl ether and/or dimethyl ether derivative and/or precursor, e.g., and methyl alcohol and composition thereof.
Referring now to Fig. 4, in the second period, by the second oil recovery fluid is injected stratum, second oil recovery fluid is introduced in stratum 111, wherein, as mentioned above, the second period started in time producing by the second well 103 mixture comprising oil and the first oil recovery fluid at the beginning.The injection process first oil recovery fluid being injected the first well 101 in the second period whole period or can proceed in the portion of time of the second period.Be produced from stratum by Mitsui 105 during the second period or in the portion of time of the second period by the first oil recovery fluid or by the first and second oil recovery fluids by the oil 121 circulated.
Pressure when second oil recovery fluid is introduced in stratum 111 by the second well 103 can the stratum instantaneous pressure of the second Jing103Chu to formation fracture pressure or exceed formation fracture pressure pressure scope in change.Pressure when second oil recovery fluid is injected in stratum can 20% to 95% of formation fracture pressure or 40% to 90% scope in change.Alternatively, can minimum be the pressure of formation fracture pressure under by second oil recovery fluid inject stratum, wherein the second oil recovery fluid can be injected under formation fracture condition.
The volume being introduced into the second oil recovery fluid in stratum 111 by the second well 103 can be changed within the scope of between the second well 103 and Mitsui 105 0.05 to 20 times of pore volume, 0.1 to 10 times of pore volume between the second well and Mitsui or the pore volume between the second well and Mitsui 0.2 to 5 times, wherein, term " pore volume between the second well and Mitsui " represents the formation volume that the second oil recovery fluid skims between the second well 101 and Mitsui 105.Pore volume between second well and Mitsui easily can be determined by the known method of those skilled in the art, such as, by analog study or by injecting stratum 111 from the second well 103 to Mitsui 105 by the water containing tracker in it.In an embodiment (will be described in more detail below) of method of the present invention, a small amount of finite volume (as, volume is 0.1 to 1 times of the pore volume between second and Mitsui) the second oil recovery fluid be injected in stratum 111 in the second period by the second well 103, continue injection first oil recovery fluid by the first well 101 simultaneously and produce flowable oil by Mitsui 105 from stratum.In another embodiment (will be described in more detail this below) of method of the present invention, a large amount of second oil recovery fluid (as volume is greater than 1 times of the pore volume between second and Mitsui) is injected in stratum in the second period by the second well 103, from stratum, produce flowable oil by Mitsui 105 simultaneously, alternatively, in the portion of time of the second period or whole second period by the first well by first oil recovery fluid continue inject stratum.
When the second oil recovery fluid was introduced in stratum 111 in the second period, the second oil recovery fluid spreads in stratum as shown in arrow 415.When the second oil recovery fluid being introduced in stratum 111 during the second period, residual oil in second oil recovery fluid contact stratum, make the flowing at least partially of the residual oil be touched, advance entering in Mitsui 105 through stratum at least partially of the residual oil 121 of this flowing.Second oil recovery fluid contact stratum at least partially, come from stratum this at least partially oil become and can to have flowed and by being removed with the first oil recovery fluid contact.Second oil recovery fluid can play the effect of the 3rd oil recovery fluid, makes the flowing at least partially (oil come from this part on stratum is processed and flows and be removed by contact first oil recovery fluid) still remaining in the residual oil in the part on stratum.The part being injected into the first oil recovery fluid in stratum by the first well 101 can enter Mitsui through stratum before the second oil recovery fluid, made oil circulation and moved to produce from Mitsui 105.Second oil recovery fluid enters Mitsui from the second well after can following a part for the first oil recovery fluid closely, can mix with a part for the first oil recovery fluid.What the second oil recovery fluid be injected into can advance the first oil recovery fluid enters Mitsui from the second well through stratum at least partially, and wherein, the first and second oil recovery fluids make oil 121 circulation to produce from Mitsui.
Referring now to Fig. 5, when well horizontal arrangement in the earth formation time, second period second period oil recovery fluid be introduced in stratum 111 by the horizontal arrangement part 203 of the second well 103, the second oil recovery fluid spreads in stratum as indicated by the arrow 515 like that.When the second period second period, oil recovery fluid one was introduced in stratum, second oil recovery fluid just contacts the oil in stratum, make the flowing at least partially of the oil be touched, be advanced in the horizontal arrangement part 205 of Mitsui 105 at least partially downwards by what become the oil that can flow.Then from stratum, the described oil 221 that can flow is produced at least partially by Mitsui 105.At least partially, the part of this oil at least partially coming from stratum 111 is processed and can flow and be removed by contact first oil recovery fluid on the second oil recovery fluid contact stratum 111.Second oil recovery fluid can play the effect of the 3rd oil recovery fluid, makes the flowing at least partially (oil come from this part on stratum is processed and can flows and be removed by contact first oil recovery fluid) still remaining in the residual oil in the part on stratum.The part being injected into the first oil recovery fluid in stratum by the horizontal arrangement part 201 of the first well 101 can be passed down through stratum and enter in the horizontal arrangement part 205 of Mitsui 105 before the second oil recovery fluid, made oil circulation and mobile to produce from Mitsui 105.Second oil recovery fluid enters the horizontal arrangement part 205 of Mitsui 105 from the horizontal arrangement part 203 of the second well 103 after can following a part for the first oil recovery fluid closely, can mix with a part for the first oil recovery fluid.First oil recovery fluid can promote downwards to make it pass stratum from the horizontal arrangement part 203 of the second well 103 to the horizontal arrangement part 205 of Mitsui 105 by the second oil recovery fluid at least partially that be injected into, wherein, the first and second oil recovery fluids make oil circulation to produce from Mitsui.
In the portion of time of the second period or during whole second period, inject the first oil recovery fluid by the first well 101.The oil that the injection process injecting the first oil recovery fluid by the first well 101 within the time at least partially of the second period promotes the first oil recovery fluid in stratum sustainably and can flow by means of the first oil recovery fluid, makes them pass stratum and enters Mitsui 105 with from wherein producing.Especially when the first oil recovery fluid ratio second oil recovery fluid and the residual oil that can flow by means of the second oil recovery fluid will thicker, the injection process injecting the first oil recovery fluid by the first well within the time at least partially of the second period also can play and the second oil recovery fluid and the residual oil that can flow by means of the second oil recovery fluid be driven in Mitsui with from the effect of wherein producing.In an embodiment of method of the present invention, within the time of at least 25% of the second period or in the time of at least 50% of the second period or during whole second period, by the first well 101, first oil recovery fluid is injected stratum 111.In another embodiment, during the second period, the first oil recovery fluid is not injected stratum.
Referring now to Fig. 6 and 7, second oil recovery fluid of a large amount of volume is introduced in stratum 111 by the second well 103 during the second period, wherein, the volume being introduced into the second oil recovery fluid in stratum can be greater than 1 times of the pore volume between the second well 103 and Mitsui 105 or respective horizontal arrangement part 203 and 205, or be greater than 2 times of described pore volume, or be greater than 3 times of described pore volume, or be 1 to 20 times of pore volume between the second well 103 and Mitsui 105 or respective horizontal arrangement part 203 and 205, or 2 to 10 times.After the second oil recovery fluid of 1 times of the pore volume be greater than by volume between the second well and Mitsui or between its respective horizontal arrangement part injects stratum, at the end of the second period, the the second oil recovery fluid 415 or 515 be injected into can extend from the second well 103 to Mitsui 105 in the fluid path in stratum, or extends from respective horizontal arrangement part 203 and 205.Producing from stratum by Mitsui 105 at least partially of the oil 121 or 221 flowed by the effect of the second oil recovery fluid of relatively a large amount of volume and the oil that flows by means of the first oil recovery fluid kept in the earth formation.
In an embodiment of method of the present invention, as shown in Figure 8, when the second oil recovery formulation of relatively a large amount of volume is introduced in stratum as described above by the second well 103, oil 122 is produced from stratum by the first well 101, and oil 121 is produced from stratum by Mitsui 105.By the first well, the injection process that the first oil recovery fluid injects stratum can be stopped when the second period started or within the Part I time of the second period; After the process being injected the first oil recovery fluid by the first well is stopped, oil can be produced from the first well 101.The part 815 being injected into the second oil recovery fluid in stratum can make to fail the oil 122 flowed by means of the first oil recovery fluid contacts with the oil in stratum flowing at least partially and driven in the first well 101 with from wherein producing.As mentioned above, another part 415 of the second oil recovery fluid can make the flowing at least partially of oil 121 and be driven in Mitsui with from wherein producing.The mode by the second well, the second oil recovery fluid being injected stratum can be adopted, the first oil recovery fluid 115 in fluid passage between the first well 101 and the second well 103 and the oil being processed and can flowing also can be circulated and be driven, to produce from the first well.
Alternatively, referring now to Fig. 9 and 10, for the pore volume between the second well 103 in stratum and Mitsui 105 or between its respective horizontal component 203 and 205, the second oil recovery fluid 915 or 1015 of a small amount of volume can be introduced in stratum by the second well during the second period.In this embodiment of the method, the volume being introduced into the second oil recovery fluid 915 or 1015 in stratum can be between the second well 103 and Mitsui 105 or 0.05 to 1 times of pore volume between its respective horizontal component 203 and 205.The second oil recovery fluid 915 or 1015 that volume is relatively little can be enough to make the major part of those residual oils do not circulated by the oil in the first oil recovery fluid contact stratum to circulate, such as, the percentage by weight at least 10% in residual oil or be at least 20% or be at least 50% part by becoming can flow with this small amount of second oil recovery fluid contact.In this embodiment, described a small amount of second oil recovery fluid 915 or 1015 is injected in stratum by the second well 103 or its horizontal arrangement part 203, continues through the first well 101 or its horizontal arrangement part 201 injects the first oil recovery fluid simultaneously.The a small amount of second oil recovery fluid 915 or 1015 be injected into can contact oil (it is failed owing to contacting the first oil recovery fluid and flows) in stratum at least partially and make it circulate.By continuing to inject this second a small amount of oil recovery fluid, this second a small amount of oil recovery fluid and become the oil 121 or 221 that can flow and can first be driven through stratum and enter Mitsui 105, with from wherein producing.
After the process injecting this second a small amount of oil recovery fluid 915 or 1015 terminates to terminate with the second period, continue through the first well 101 or its horizontal component 201 injects the first oil recovery fluid 115 or 215 in the 3rd period, wherein the 3rd period the second period once at the end of start.Injection first oil recovery fluid is continued by the first well, thus, stratum can be driven through at this small amount of second oil recovery fluid 915 or 1015 of the 3rd period and processed and oil 121 or 221 that is that can flow and enter Mitsui 105 or its horizontal component 205, with from wherein producing.Alternatively, when first oil recovery fluid being continued to inject stratum by the first well 101 or its horizontal component 201, or by the first well by first oil recovery fluid inject stratum process stop after, the 3rd period first period oil recovery fluid be injected in stratum by the second well 103 or its horizontal component 203.
Oil is produced from stratum by Mitsui 105 for 121 or 221 (comprising the oil circulated owing to contacting the first oil recovery fluid and the residual oil circulated owing to contacting the second oil recovery fluid).A part for first oil recovery fluid, a part for the second oil recovery fluid and formation water are also produced from stratum 111 by Mitsui 105.Can being continued during first, second, and third period by the process of Mitsui 105 produce oil from stratum 111, wherein, when not having sufficient oil by output, can stop producing to allow process economics.
The present invention is extremely suitable for achieving the above object and advantage and the intrinsic advantage of the present invention.Above-mentioned specific embodiment is only illustrative, because the present invention can be modified in different but equivalent mode and implement, aforesaid way is apparent for the those skilled in the art that can be benefited from instruction herein.In addition, be not intended to be limited to the details of the construction or design shown in literary composition, except described in claims below.Although come descriptive system and method by the wording of " comprising ", " containing " or " comprising " various element or step, composition and method also can roughly be made up of various element and step or be made up of various element and step.No matter when disclose the number range with lower limit and the upper limit, fall into any numerical value within the scope of this and any scope within it of comprising also by specifically open.Specifically, each number range disclosed herein (with the form of " a to b " or equally with the form of " a-b ") should be understood to, has set forth and has been included in each numeral in wider number range and scope.No matter when disclose and only have certain lower limit value or only have specific higher limit or have the number range of specific higher limit and certain lower limit value, this scope also comprises any numerical value being roughly this certain lower limit value and/or this specific higher limit.In addition, the term in claim has general common meaning, limits unless patentee is clearly clear in addition.In addition, the indefinite article "a" or "an" (a, an) in claims is restricted to the element representing that this paper of one or more than one introduces in the text.
Claims (13)
1., for a method for recovery of oil from oil-bearing layer, it comprises the following steps:
In the first period, by the first well extended in stratum, the first oil recovery fluid is injected oil-bearing layer, produce fuel-displaced from stratum by the second well extended in stratum;
In the second period, by the second well, the second oil recovery fluid is injected stratum, produce fuel-displaced from stratum by the Mitsui extended in stratum, wherein, in the fluid flow path being between the first well and Mitsui of the second well location in stratum; Wherein, the first oil recovery fluid and the second oil recovery fluid have different compositions; Wherein, the second period was after the first period of time, the second period when produced the mixture comprising oil and the first oil recovery fluid at the beginning from stratum by the second well just.
2. method according to claim 1, further comprising the steps of: in the 3rd period, by the first well, the first oil recovery fluid is injected stratum, produce fuel-displaced from stratum by Mitsui; Wherein, the 3rd period by the second well by second oil recovery fluid inject stratum process once at the end of start.
3. method according to claim 1 and 2, further comprising the steps of: within the time at least partially of the first period, to be produced oil from stratum by Mitsui.
4. the method according to the arbitrary claim in claim 1 or claim 2-3, wherein, second period just started in time producing the mixture comprising oil, formation water and the first oil recovery fluid at the beginning, and the first oil recovery fluid in this mixture and the gross weight of formation water are at least 1:1 with the ratio of weight of oil.
5. the method according to the arbitrary claim in claim 1 or claim 2-4, wherein, the first oil recovery fluid is water or salt solution.
6. the method according to the arbitrary claim in claim 1 or claim 2-5, wherein, the second oil recovery fluid is selected from the group be made up of following material: total dissolved solidss content is 200ppm to 10000ppm and ionic strength is up to the water of 0.15M; Salt solution; The aqueous solution of the composition of aqueous surfactant solution or kinds of surface activating agent; Alkali, surfactant and polymer preparation; The aqueous solution of water-soluble polymer; The aqueous solution of ether or ether.
7. the method according to the arbitrary claim in claim 1 or claim 2-6, wherein, by volume for a small amount of second oil recovery fluid of 0.1 to 1 times of the pore volume surveyed between the second well and Mitsui injects stratum.
8. the method according to the arbitrary claim in claim 1 or claim 2-7, wherein, first well is by a part for the array of 2 to 500 mouthful of first well construction, second well is by a part for the array of 2 to 100 mouthful of second well construction, Mitsui is by a part for the array of 2 to 100 mouthful of the 3rd well construction, wherein, in the fluid flow path between corresponding first well and corresponding Mitsui of each second well location in stratum.
9. the method according to the arbitrary claim in claim 1 or claim 2-8, wherein, described stratum, the first well, the second well and Mitsui are positioned at coastal waters.
10. the method according to the arbitrary claim in claim 1 or claim 2-9, further comprising the steps of: within the time at least partially of the second period, by the first well, the first oil recovery fluid is injected stratum.
11. methods according to claim 1, wherein, when the first oil recovery fluid one is injected in stratum, the first oil recovery fluid be injected into just makes oil circulation to produce from stratum; When the second oil recovery fluid one is injected in stratum, the second oil recovery fluid be injected into just makes residual oil circulate to produce from stratum, and wherein, described residual oil is can by means of the oil flowed by the first oil recovery fluid matasomatism.
12. methods according to claim 1, further comprising the steps of: to produce fuel-displaced within the time at least partially of the second period from stratum.
13. methods according to claim 1, wherein the first well and Mitsui are separated by least 1km.
Applications Claiming Priority (3)
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| US201361829697P | 2013-05-31 | 2013-05-31 | |
| US61/829,697 | 2013-05-31 | ||
| PCT/US2014/039923 WO2014194031A1 (en) | 2013-05-31 | 2014-05-29 | Process for enhancing oil recovery from an oil-bearing formation |
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| CN105247165A true CN105247165A (en) | 2016-01-13 |
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| CN201480030946.0A Pending CN105247165A (en) | 2013-05-31 | 2014-05-29 | Process for enhancing oil recovery from an oil-bearing formation |
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| US (1) | US20140352958A1 (en) |
| EP (1) | EP3004533A1 (en) |
| CN (1) | CN105247165A (en) |
| CA (1) | CA2910988A1 (en) |
| EA (1) | EA201592230A1 (en) |
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| CN111587313A (en) * | 2017-09-12 | 2020-08-25 | 英国石油勘探运作有限公司 | Method for controlling salinity of low salinity injection water |
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| US20170218260A1 (en) * | 2016-01-28 | 2017-08-03 | Neilin Chakrabarty | DME Fracing |
| GB2559410B (en) * | 2017-02-06 | 2020-04-15 | Equinor Energy As | Method |
| US20170327730A1 (en) * | 2017-08-02 | 2017-11-16 | Shell Oil Company | Hydrocarbon recovery composition and a method for use thereof |
| US20220314167A1 (en) * | 2019-05-07 | 2022-10-06 | Bl Technologies, Inc. | Seawater treatment to obtain high salinity water with low hardness for enhanced oil recovery |
| US20240067866A1 (en) * | 2022-08-23 | 2024-02-29 | Saudi Arabian Oil Company | Ether and carbon dioxide mixtures to enhance hydrocarbon recovery from an underground formation |
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| CN111587313A (en) * | 2017-09-12 | 2020-08-25 | 英国石油勘探运作有限公司 | Method for controlling salinity of low salinity injection water |
Also Published As
| Publication number | Publication date |
|---|---|
| EA201592230A1 (en) | 2016-04-29 |
| US20140352958A1 (en) | 2014-12-04 |
| CA2910988A1 (en) | 2014-12-04 |
| EP3004533A1 (en) | 2016-04-13 |
| WO2014194031A1 (en) | 2014-12-04 |
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