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CN102763118B - Systems and methods for producing oil and/or gas - Google Patents

Systems and methods for producing oil and/or gas Download PDF

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Publication number
CN102763118B
CN102763118B CN201180010305.5A CN201180010305A CN102763118B CN 102763118 B CN102763118 B CN 102763118B CN 201180010305 A CN201180010305 A CN 201180010305A CN 102763118 B CN102763118 B CN 102763118B
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well
oil
optimum
asp
potpourri
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CN102763118A (en
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W·M·斯托尔
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Shell Internationale Research Maatschappij BV
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Shell Internationale Research Maatschappij BV
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V11/00—Prospecting or detecting by methods combining techniques covered by two or more of main groups G01V1/00 - G01V9/00
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/66—Subsurface modeling

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Lubricants (AREA)

Abstract

A method for producing oil and/or gas from an underground formation comprising locating a suitable reservoir in a subsurface formation; creating a model of the reservoir; populating the model with laboratory data; modeling the reservoir to determine fluid displacements based on fluids injected and fluids produced; determining an optimum fluid mixture for the fluids to be injected based on a series of sensitivity analyses performed with the model; drilling a first well in the formation; injecting the optimum fluid mixture into the first well; drilling a second well in the formation; and producing oil and/or gas from the second well.

Description

Produce oil and/or the system and method for gas
Technical field
The present invention relates to and produce oil and/or the system and method for gas.
Background technology
Enhanced oil recovery (EOR) can worldwide be used for increasing the oil recovery in oil field.There is the EOR of three kinds of main Types, instant heating, chemicals/polymkeric substance and gas inject, they can be used to the oil recovery increasing storage layer, make it to exceed the petroleum production that classic method may reach, thus likely Yanchang Oilfield life-span and improve oil recovery.
Hot enhanced recovery is by working to the heating of storage layer.The form of most widespread use is steam flood, which reduces oil viscosity thus oil can flow to producing well.The chemical displacement of reservoir oil by reduce retain Residual oil capillary force and/or reduce oil and water between interfacial tension and increase oil recovery.Polymer flooding improves the displacement sweep efficiency injecting water.Miscible thing inject by produce easier than oil itself flow to producing well injectant and oily potpourri and working.
With reference to figure 1, which describe the system 100 of prior art.System 100 comprises subsurface formations 102, subsurface formations 104, subsurface formations 106 and subsurface formations 108.Production facility 110 is provided on ground.Well 112 through stratum 102 and 104, and ends at stratum 106.Formation 106 represents at 114 places.Oil is gentle to be produced to production facility 110 by well 112 by ground layer segment 114.Gas is separated each other with liquid state, and gas storage exists gas storage facility 116 neutralising fluid and is stored in liquid storage equipment 118.
US Patent No. 6, 022, the 834 a kind of methods disclosing concentrated surfactant formulatory agent and Residual oil of gathering from oilbearing stratum, it is more specifically a kind of alkaline surfactant's flooding method, the method can cause interfacial tension ultralow between injecting material and Residual oil, wherein said concentrated surfactant formulatory agent concentration higher than, supply under being equal to or less than its CMC concentration, described patent additionally provides and forms surface active material by the reaction original position between naturally occurring organic acidity component and the basic matterial of injection, described surface active material is used for increasing oil-production efficiency.US Patent No. 6,022,834 which is hereby incorporated by reference.
US Patent No. 5,068,043 disclose a kind of for driving method from the aqueous bases of storage layer recovery of oil containing acid-soluble oil, the alkaline aqueous solution that described method comprises to injecting adds the basic matterial of stoichiometric excess and the preformed cosurfactant material of certain kind and quantity, the latter will increase the salinity of described solution, thus when contacting with the oil in storage layer, formation salinity requirements can be minimized the surfactant system of interfacial tension between itself and oil.US Patent No. 5,068,043 which is hereby incorporated by reference.
The U.S. Patent Application Publication US 2009/0194276 being disclosed on August 6th, 2009 discloses the system and method determining the optimum salinity type of surfactant microemulsion system and optimum salinity.The optimum salinity type of the Surfactant/Polymer displacement of reservoir oil and optimum salinity are determined by core oil displacement experiment, thus multiple polyphasic flow parameter is as the relative permeability affecting oil recovery and the determination retained the optimum salinity type of impact and optimum salinity mutually etc.Determined optimum salinity preferably corresponds to the highest oil recovery.Which is hereby incorporated by reference for U.S. Patent Application Publication US 2009/0194276.
The U.S. Patent Application Publication US 2009/0194281 being disclosed on August 6th, 2009 discloses the optimum salinity profile causing the highest oil recovery in the Surfactant/Polymer displacement of reservoir oil by the displacement of reservoir oil of local water post-flush.The optimum salinity determined by core oil displacement experiment may be used for surfactant slug.Before and after injecting surfactant slug to storage layer, inject buffer plug immediately deterioration does not occur to protect surfactant slug, wherein said buffer plug has the salinity identical or roughly the same with surfactant slug.Lower salinity may be used in the post-flush displacement of reservoir oil, and local water can be any salinity.Which is hereby incorporated by reference for U.S. Patent Application Publication US2009/0194281.
Improved system and the method for enhanced oil recovery is needed in this area.Also need improved system and the method for using basic surfactant polymer (ASP) displacement of reservoir oil in this area, such as by increase injectant viscosity, reduce interfacial tension between injectant and oil, utilize injectant and oil forms emulsion and/or other chemical effect is carried out.Improved system and the method for the ASP displacement of reservoir oil is also needed in this area.
Summary of the invention
In one aspect, the invention provides and a kind ofly to produce oil and/or the method for gas from subsurface formations, described method comprises: in subsurface formations, locate suitable storage layer; Set up storage layer model; Use laboratory data loaded with dielectric; Simulation storage layer is to determine based on the fluid substitution of injected fluid with the fluid produced; The optimum fluid mixture of fluid to be implanted is determined based on a series of sensitivity analysis carried out with model; Drill the first well in the earth formation; Optimum fluid mixture is injected in the first well; Drill the second well in the earth formation; Produce oil and/or gas with by the second well.
Advantage of the present invention comprises one or more as follows:
The improved system of gathering with ASP displacement of reservoir oil strengthening stratum hydrocarbon and method.
The improved system of gathering with the hydroenhancement stratum hydrocarbon containing the ASP displacement of reservoir oil and method.
The improvement composition of gathering for secondary and/or three hydrocarbon and/or technology.
For improved system and the method for enhanced oil recovery.
The improved system of the enhanced oil recovery of the application ASP displacement of reservoir oil and method.
Application has improved system and the method for the enhanced oil recovery of the compound of the viscosity of increase and the interfacial tension of reduction compared with water.
Accompanying drawing explanation
Fig. 1 describes the production system of oil and/or gas.
Fig. 2 a describes the distribution of well.
Fig. 2 b and 2c describes the distribution of the well of Fig. 2 a in enhanced oil recovery processes.
Fig. 3 describes oil and/or gas production system.
Fig. 4 describes the distribution of well.
Fig. 5 describes the potpourri of crude oil and salt solution.
Fig. 6 describes the potpourri of crude oil and salt solution.
Fig. 7 describes the result of core oil displacement experiment.
Fig. 8 describes the result of core oil displacement experiment.
Fig. 9 describes the result of core oil displacement experiment.
Figure 10 describes the simulation of the lab scale ASP displacement of reservoir oil.
Figure 11 describes the relation between the optimum salinity of surfactant and the optimum salinity of soap.
It is the distribution of benchmark soap and surfactant that Figure 12 describes with salinity.
Figure 13 describes the result of well daily record.
Figure 14 describes the oil field data of single well chemical tracer test.
Figure 15 describes the oil field data of single well chemical tracer test.
Figure 16 describes the simulation of the lab scale ASP displacement of reservoir oil.
Embodiment
Accompanying drawing 2a:
Below with reference to the accompanying drawings 2a, which describes well array 200 in some embodiments.Array 200 comprises well group 202 (being represented by horizontal line) and well group 204 (being represented by oblique line).
Array 200 defines the mining area by rectangular closed.Array 200 defines the inside of system.In array 200 outside, multiple plugged well 250 can be set.
Each well in well group 202 and the adjacent well in well group 202 have horizontal range 230.Each well in well group 202 and the adjacent well in well group 202 have vertical range 232.
Each well in well group 204 and the adjacent well in well group 204 have horizontal range 236.Each well in well group 204 and the adjacent well in well group 204 have vertical range 238.
Just as shown in Figure 2 a, horizontal range 230 and horizontal range 236 all to refer on paper distance from left to right, and vertical range 232 and vertical range 238 all to refer on paper distance from top to bottom.In fact, array can by perpendicular to earth's surface perpendicular hole, be parallel to earth's surface horizontal well or relative to earth's surface with some other angles such as 30-60 degree tilt well construction.
Each well in well group 202 and the distance between the adjacent well in well group 204 are 234.Each well in well group 204 and the distance between the adjacent well in well group 202 are 234.
In some embodiments, each well in well group 202 surround by the well of four in well group 204.In some embodiments, each well in well group 204 surround by the well of four in well group 202.
In some embodiments, horizontal range 230 is about 25-1000 rice, or about 30-500 rice, or about 35-250 rice, or about 40-100 rice, or about 45-75 rice, or about 50-60 rice.
In some embodiments, vertical range 232 is about 25-1000 rice, or about 30-500 rice, or about 35-250 rice, or about 40-100 rice, or about 45-75 rice, or about 50-60 rice.
In some embodiments, horizontal range 236 is about 25-1000 rice, or about 30-500 rice, or about 35-250 rice, or about 40-100 rice, or about 45-75 rice, or about 50-60 rice.
In some embodiments, vertical range 238 is about 25-1000 rice, or about 30-500 rice, or about 35-250 rice, or about 40-100 rice, or about 45-75 rice, or about 50-60 rice.
In some embodiments, distance 234 is about 15-750 rice, or about 20-500 rice, or about 25-250 rice, or about 30-100 rice, or about 35-75 rice, or about 40-50 rice.
In some embodiments, well array 200 can have about 10-1000 mouth well, 5-500 mouth well of such as having an appointment in well group 202, and 5-500 mouth well of having an appointment in well group 204.Optionally, about 2-1000 mouth plugged well 250 can be provided, such as about 5-500 mouth, or about 10-200 mouth.
In some embodiments, well array 200 is considered to be at the well group 202 of the perpendicular hole at interval on a piece of land and the vertical view of well group 204.In some embodiments, well array 200 is counted as the well group 202 of the horizontal well at interval in stratum and the cross sectional side view of well group 204.
Can be come by any known method from subsurface formations recovery of oil and/or gas with well array 200.Suitable method comprise obtaining from underwater installation, surface mining, once, secondary or tertiary recovery.Selection for the method from subsurface formations recovery of oil and/or gas is not critical.
In some embodiments, can be realized by any known method with plugged well 250 shutoff oil and/or gas and/or enhanced oil recovery reagent.Suitable method to comprise in plugged well 250 pumps water, steam, the primitive water produced, seawater, carbon dioxide, rock gas or other gaseous state or liquid hydrocarbon, nitrogen, air, salt solution or other liquid or gas.In another embodiment, plugged well 250 can be used for formation and freezes obstacle.In US Patent No. 7,225, disclose in 866 and a kind ofly suitable freeze obstacle, which is hereby incorporated by reference for this patent.Selection for the method with plugged well 250 shutoff oil and/or gas and/or the use of enhanced oil recovery reagent place is not critical.
In some embodiments, oil and/or gas can be gathered well from stratum, and flow through well and flowline enters in facility.In some embodiments, utilize the enhanced oil recovery of the ASP potpourri such as potpourri of water, alkali, surfactant and polymkeric substance can be used for strengthen oil and/or gas from the flowing stratum.
Accompanying drawing 2b:
Below with reference to the accompanying drawings 2b, which describes well array 200 in some embodiments.Array 200 comprises well group 202 (representing with horizontal line) and well group 204 (being represented by oblique line).Optional plugged well 250 is provided around well array 200.
In some embodiments, in well group 204, inject ASP potpourri, and from well group 202 recovery of oil.As shown in the figure, ASP potpourri has injection curve 208, and produces oil recovery curve 206 in well group 202.In some embodiments, in plugged well 250, shutoff reagent is injected.As shown in the figure, shutoff reagent has the injection curve around each plugged well 250.Shutoff reagent can be used for ordering about ASP potpourri and/or oil and/or gas and enters output well group 202.
In some embodiments, ASP potpourri injects well group 202, and by well group 204 recovery of oil.As shown in the figure, ASP potpourri has injection curve 206, and oil recovery curve 208 produces to well group 204.In some embodiments, shutoff reagent injects plugged well 250.As shown in the figure, shutoff reagent has the injection curve around each plugged well 250.Shutoff reagent can be used for ordering about ASP potpourri and/or oil and/or gas and enters output well group 204.
In some embodiments, well group 202 can be used to inject ASP potpourri, and well group 204 can be used to be produced oil and/or gas by stratum in first time period; Then well group 204 can be used to inject ASP potpourri, and well group 202 can be used to be produced oil and/or gas by stratum within the second time period, and the first and second time periods formed one-period.
In some embodiments, ASP potpourri or the potpourri comprising ASP potpourri can inject when the cycle starts, and can inject the water being optionally added with polymkeric substance when end cycle and enter producing well to promote ASP potpourri.In some embodiments, the incipient stage in cycle can be the initial 10-about 80% in cycle, or the initial 20-about 60% in cycle, the initial 25-about 40% in cycle, and the end cycle period is the remainder in cycle.
In some embodiments, the water being optionally added with polymkeric substance can be used as shutoff reagent and be injected in plugged well 250.
In some embodiments, the ASP potpourri being injected into stratum can reclaim from the oil of extraction and/or gas, and re-injects in stratum.
In some embodiments, the oil viscosity existed in the earth formation before injecting any enhanced oil recovery reagent is at least about 5 centipoises, or at least about 10 centipoises, or at least about 25 centipoises, or at least about 50 centipoises, or at least about 75 centipoises, or at least about 90 centipoises.In some embodiments, injecting the oil viscosity that exists in the earth formation before any enhanced oil recovery reagent for about 125 centipoises at the most, or about 200 centipoises at the most, or about 500 centipoises at the most, or about 1000 centipoises at the most.
Accompanying drawing 2c:
Below with reference to the accompanying drawings 2c, which describes well array 200 in some embodiments.Array 200 comprises well group 202 (representing with horizontal line) and well group 204 (representing with oblique line).Plugged well 250 is positioned at the outside of array 200 to form the periphery around array 200.
In some embodiments, in well group 204, inject ASP potpourri, and from well group 202 recovery of oil.As shown in the figure, the injection curve 208 of ASP potpourri has overlapping 210 with oil recovery curve 206, and oil recovery curve 206 produces to well group 202.In some embodiments, in plugged well 250, shutoff reagent is injected.As shown in the figure, shutoff reagent has the injection curve around each plugged well 250.Shutoff reagent can be used for ordering about ASP potpourri and/or oil and/or gas and enters output well group 202.After time enough section, shutoff reagent inject curve can with inject the one or more overlapping of curve 208 and oil recovery curve 206, thus enhanced oil recovery reagent by shutoff in array 200; And/or make oil and/or sealing gland get lodged in array 200; And/or make shutoff reagent output to well group 202.
In some embodiments, in well group 202, inject ASP potpourri, and from well group 204 recovery of oil.As shown in the figure, the injection curve 206 of ASP potpourri has overlapping 210 with oil recovery curve 208, and oil recovery curve 208 produces to well group 204.In some embodiments, in plugged well 250, shutoff reagent is injected.As shown in the figure, shutoff reagent has the injection curve around each plugged well 250.Shutoff reagent can be used for ordering about ASP potpourri and/or oil and/or gas and enters output well group 204.After time enough section, shutoff reagent inject curve can with inject the one or more overlapping of curve 208 and oil recovery curve 206, thus enhanced oil recovery reagent by shutoff in array 200; And/or make oil and/or sealing gland get lodged in array 200; And/or make shutoff reagent output to well group 204.
Discharge ASP potpourri and/or other liquid and/or gas at least partially to be realized by any known method.Suitable method, for inject an ASP potpourri in the first well, and pumps out ASP potpourri at least partially by the second well together with described gas and/or liquid.Selection for the method being used for injecting ASP potpourri and/or other liquid and/or gas is at least partially not critical.
In some embodiments, ASP potpourri and/or other liquid and/or gas pump can be sent into stratum under up to the pressure of formation fracture pressure.
In some embodiments, ASP potpourri can mix to form the potpourri can gathered by well with the oil in stratum and/or gas.
In some embodiments, by a certain amount of ASP potpourri Injection Well, another component can be injected subsequently to order about ASP potpourri through stratum.Such as, for liquid or gaseous form water, can be used to order about ASP potpourri through stratum to increase the water of its viscosity, carbon dioxide, other gas, other liquid and/or their potpourri containing the polymkeric substance dissolved.
In some embodiments, the ASP potpourri of about 0.1-5 pore volume can be injected, such as, can inject the ASP potpourri of about 0.2-2 pore volume or about 0.3-1 pore volume.ASP potpourri then can inject the polymer water potpourri of about 2-10 pore volume after injecting, the such as polymer water potpourri of about 3-8 pore volume.Polymer water potpourri then can inject the water of about 1-10 pore volume after injecting.
Accompanying drawing 3:
Below with reference to the accompanying drawings 3, which describe system 400 in some embodiments of the present invention.System 400 comprises subsurface formations 402, stratum 404, stratum 406 and stratum 408.Production facility 410 is provided on the ground.Well 412 through stratum 402 and 404, and has perforate at stratum 406 place.Formation 414 can optionally pressure break and/or perforate.When oil gentle by stratum 406 output time, their entering parts 414 are also advanced into production facility 410 along on well 412.By gas and fluid separation applications, and gas can be delivered in gas storage facility 416, and liquid is delivered in liquid storage equipment 418.Production facility 410 can mix, produces and/or store ASP potpourri, and ASP potpourri can produce and store in production/bunkerage 430.
ASP potpourri pumps into well 432 downwards, to the part 434 on stratum 406.ASP potpourri is gentle with supplement production oil through stratum 406, and then ASP potpourri, oil and/or gas all output to well 412, can arrive production facility 410.Then ASP potpourri can circulate, and such as, by application oil-water gravity separator, hydro-extractor, emulsion breaker, boiling, condensation, filtration and other separation method well known in the prior art, is then refilled in well 432 by ASP potpourri.
The plugged well 450 with injecting mechanism 452 and the plugged well 460 with injecting mechanism 462 can be provided, with shutoff ASP potpourri between plugged well 450 and plugged well 460.Injecting mechanism 452 and 462 can be used to inject shutoff reagent, as produced the refrigerant of freezing wall or liquid or gas as water, the water mixed with tackifier, the water mixed with alkali, the water mixed with surfactant, carbon dioxide, rock gas, other C 1-C 15hydrocarbon, nitrogen or air or their potpourri.
In some embodiments, a certain amount of ASP potpourri or the ASP potpourri mixed with other component can be injected in well 432, then another kind of component is injected with the ASP potpourri ordering about ASP potpourri or mix with other component through stratum 406, the water of such as gaseous state or liquid state, the water mixed with one or more salt, polymkeric substance, alkali and/or surfactant; Carbon dioxide; Other gas; Other liquid; And/or their potpourri.
In one embodiment, can by the ASP potpourri Injection Well 432 of about 0.1-2 such as about 0.25-1 pore volume.Then the viscosity of about 0.5-10 such as about 1-5 pore volume to be about within ASP mixture viscosity 25% in the polymer-water mixtures Injection Well 432 according to appointment within 10%.Then by the water Injection Well 432 of about 1-10 pore volume.
In some embodiments, to produce oil and/or the well 412 of gas is the representative of well in well group 202, and the well 432 for injecting ASP potpourri is representatives of well group 204 well.
In some embodiments, to produce oil and/or the well 412 of gas is the representative of well in well group 204, and the well 432 for injecting ASP potpourri is representatives of well group 202 well.
Accompanying drawing 4:
Figure 4 depicts the method 500 that design ASP drives.Method 500 comprises the optimum salinity determining surfactant 502, the optimum salinity determining soap 504, determines mixture viscosity owing to the addition of polymkeric substance 506, comprise stratum, the model 508 of chemicals and oily characteristic, correlation model and given data 510 and application model and design ASP for ASP drives to set up and drive 512.Further details for each step is described below.
ASP method is that two kinds of chemical displacement of reservoir oil technology comparatively early and surfactant and polymer drive the combination of driving with alkali.In these methods, the task of the chemicals injected is dual: first, reduces the oil that the interfacial tension between profit is retained by capillary force with release; And next, as necessary, stablize described displacement by adding the viscosity of polymkeric substance increase water.When surfactant and polymer drives, the injection surfactant that is decreased through of interfacial tension realizes.And when alkali drives, alkali (such as NaOH or Na 2cO 3improve the pH value of salt solution, this can cause the oleic acid saponification of crude oil carrier band conversely, thus original position produces the natural surfactant being commonly referred to " soap ".
Although the surfactant (hereinafter referred to as " surfactant ") injected and the surfactant that original position produces (being called " soap ") are chemically obviously different, but they have unified performance, namely their interfacial activities depend on that environment is as salinity.Except constant external condition, there is optimum brine salinities, farthest reduce oil-water interfacial tension at this optimum brine salinities lower surface activating agent or soap.
At comparatively Low-salinity (" lower than optimum state ") or under comparatively high salinity (" higher than optimum state "), the reduction of interfacial tension is less.Lower than under optimum state, surfactant and soap are conducive to being dispensed into salt aqueous phase; Higher than under optimum state, they are conducive to being dispensed into oil phase; Only when close to their respective optimum salinity, they could produce the 3rd independent " microemulsion phase ", this phase and all show extremely low interfacial tension between oil phase and aqueous phase.Optimum salinity is specific for surfactant; The optimum salinity of soap usually obviously will lower than typically injecting surfactant.
Can design ASP potpourri make the optimum salinity of chemical slug close to or equal to inject the actual brine salinities of water, thus realize low oil-water interfacial tension.High or low salinity will make surfactant or soap effectively can not be pushed into producing well (lower than optimal situation) or be assigned with to enter in fixing oil, be namely retained in oil, therefore lost (higher than optimal situation).
ASP potpourri can comprise the alkali, surfactant and the polymkeric substance that inject together as a slug.In this slug, alkali and surfactant move with the speed that (a little) is different usually: surfactant is dispensed into the neutralization of any irreducible oil and carries out matrix absorption, and alkali by saponification, carbonate deposition and may with matrix exchange reaction and being consumed.
After the implantation, ASP slug phase behavior lower than or close to optimum state.Then, after alkali contacts with crude oil, saponification process reduces the optimum salinity of producing soap region, thus the phase behavior of local is changed to higher than optimum state.Result establishes optimum salinity, and in chemical slug front end, higher than optimum, extremely chemical slug rear end is lower than the gradient of optimum, and this gradient limits chemical slug and limits dispersion dilution.This intrinsic gradient by the expansion of storage layer, thus can move optimum interfacial activity district by storage floor in principle, causes not having oil remaining.
Determine the optimum salinity of surfactant phase:
In order to determine the chemical phase behavior of surfactant, the series of samples with Different Alkali and common salt concentration can be applied, such as test tube.Such example is in zero alkali concn, can be inferred the optimum salinity of pure surfactant solution as shown in Figure 5 by this sample.Can infer that the test tube producing independent emulsion phase is in or close to optimum salinity, thus interfacial tension be reduced to maximal value.
Determine the optimum salinity of soap phase:
In order to determine the chemical phase behavior of soap, substantially according to the program identical with determining surfactant, just a little complicated.Soap is the reactor product of alkali or oxyhydroxide and oleic acid more specifically.Thus, produce soap amount and depend on the alkali number joined in salt solution.
But add alkali and also increase salinity, therefore can not study and the behavior under the Low-salinity of high soap concentration combination.Application sodium carbonate is when making alkali, and the most simple form controlling the balanced reaction of saponification is aqueous reaction:
Na 2cO 3→ 2Na ++ CO 3 2-(formula 1)
(formula 2)
And saponification: (formula 3)
In formula 3, HA orepresent oil and carry acid, A -represent soap.Due to HA o+ OH -be present in oil and water respectively, occur in the interface of You Heshui according to a reaction after understanding.
Be decided by that namely " total acid number " (TAN) of oil measure the amount of the volumetric molar concentration of acid in oil, need the alkali of different amount to realize fully saponified.Relatively the volumetric molar concentration of carbonate and acid can show the saponification that whether there occurs obvious degree in given oil and saline mixture.
Determine the viscosity of polymer solution:
In order to determine the viscosity of polymer solution, the sample with different salinity can be made to have the polymkeric substance of the given volume made an addition to wherein, and then determine the viscosity of sample.Usually, increase salinity and will cause comparatively low viscosity, and the volume increasing polymkeric substance will cause viscosity higher.
In one embodiment, the mobility ratio of ASP potpourri is mated with the oil in stratum.Usually, the mobility ratio of ASP potpourri and oil is the function of viscosity.Therefore, in ASP potpourri, add polymkeric substance until the viscosity of this potpourri and oils seemingly.In one embodiment, the viscosity number of ASP potpourri within 50% of oil viscosity value, such as, within 20% or within 10%.
Modling model:
In brief, model be ASP method two-phase (water and oil) polycomponent (surfactant, acid, soap, polymkeric substance, containing water chemistries) description, comprise salt water chemistry, chemicals composition rely on distribute, absorption and viscosity adjustment.
Model comprises two liquid phases (water and oil) and a fixing solid phase, and wherein surfactant and soap distribute between two liquid phases according to the ratio of salinity and optimum salinity.
A central feature of ASP potpourri discussed above is by being converted to higher than optimum behavior (Fu Zaoqu) lower than optimum behavior (rich surfactant district).Because given position soap changes with surfactant concentration ratio in storage layer, be therefore necessary for optimum salinity.Surfactant and soap optimum salinity is separately as the input parameter that can be determined by experiment.
Surfactant and soap all allow to distribute between water and oil as the function of topical chemicals concentration (phase composition).This distribution determines the flowing of surfactant and soap.The basis of apportion model is along with partial groups becomes to be respectively lower than qualitative observation that is optimum or that be strongly dispensed into higher than optimal tables surface-active agent and soap in water or oil.But at optimum salinity place, surfactant and soap are dispensed in water and oil with equal portions.Due to ASP drive may leading surfactivity band higher than optimum and in described band lower than optimum, the true character of partition factor may be not too relevant.
Provide interfacial tension association in a model.This association supposition obtains user-defined minimum interfacial tension at optimum salinity place.In addition, at high soap with surfactant concentration than locating, establish minimum interfacial tension due to soap.Finally, if total surfactant concentration (i.e. the summation of surfactant and soap concentration) is or higher than critical micelle concentration, then can only realizes minimum interfacial tension.When the total concentration of soap and surfactant reduces, interfacial tension moves closer to unadjusted oil-water number.
This model has Viscosity Model, it considers the dependence of viscosity to polymer quality mark and effective salinity in water.
Saponification degree depends on local base concentration.Therefore, the concentration of the acid and other component following the tracks of this concentration and affect soap generation is the feature of ASP model.In order to avoid simulated time is long, the number of reactant can be the least possible, comprises saponification equation described above.
The complicacy of the ASP displacement of reservoir oil and ASP model and the model simplification of necessity require that the prediction that model produces is effective.For this reason, can detailed One-dimensional simulation be carried out, and the chemicals of gained and productive frontiers and other model or other given data are compared.Subsequently, the ASP core of experiment drives data and can mate with historical data, with the data correlation making model and described core drive generation.Then site of deployment experiment and the industrial scale data by the acquisition of storage layer improve this model further.
Design ASP potpourri
Once successfully devise model and be provided with parameter for given oil field or stratum, then this model can be used to the component determining ASP potpourri.Under the complicacy of given multiple parameter and composite chemical, a suitable starting point may be the ASP potpourri chemistry applied above, or applies the optimum potpourri chemistry determined by laboratory experiment discussed above.Thus, the salinity of potpourri may change, and the concentration of surfactant, the concentration of polymkeric substance and paper mill wastewater all may change simultaneously.Model may need to demarcate further by the test of additional laboratory and experiment, thus the suitably salinity of analog variation, surfactant concentration, polymer concentration and/or alkali concn.
In one embodiment, the sensitivity analysis that first can complete surfactant concentration, to realize optimum surfactant concentration, is carried out identical analysis to alkali subsequently, and then is analyzed polymkeric substance.But order is not critical.
Usually, the oil recovery of increase is compared with the cost of the chemicals of the optimum potpourri of acquisition.
Replacement scheme:
In some embodiments, the oil produced and/or gas can be delivered in refinery and/or treatment facility.Oil and/or gas can be processed with manufacture product if transport fuel is as gasoline and diesel oil, heater oil, lubricant, chemicals and/or polymkeric substance.Process can comprise oil and/or gas described in rectifying and/or fractionation to produce one or more distillate cut.In some embodiments, oil and/or gas and/or one or more distillate cut can experience one or more methods following: catalytic cracking, hydrocracking, hydrotreating, coking, thermal cracking, distillation, reformation, polymerization, isomerization, alkylation, blended and dewaxing.
Embodiment:
From designing suitable ASP preparaton to oil field this route of actual lab scale for evaluating and verify the feasibility of ASP project large-scale sandstone storage layer.
Laboratory work and model calibration
Need a set of laboratory experiment to quantize the behavior of ASP preparaton.During beginning, analyze separately phase behavior and the polymer viscosity behavior of surfactant mixture.Subsequently, both is combined in core oil displacement experiment the oil recovery studying given combination, and demarcate flow simulating for predicting subsequently.
Phase behavior is tested
In order to this purpose, can think surfactant mixture by two kinds independently material form: the petroleum soap that the injection surfactant produced and original position produce.Although say that both has visibly different molecular structure in principle, they all have the ability (although under different brine salinities) reducing interfacial tension between crude oil and salt solution, assuming that other macroscopic properties all determine by storing layer.Salinity when given surfactant reaches minimum interfacial tension is called its optimum salinity.Low interfacial tension promotes the generation of oil-salt aqueous emulsion phase, and this can be used as the evidence reaching optimum salinity conversely.Together with interfacial activity, surfactant depends on salinity in the distribution oily, salt solution is alternate with emulsion: under optimum salinity, surfactant is dispensed into emulsion phase; Under the salinity lower than optimum salinity (lower than optimal situation), surfactant is mainly dispensed into salt solution; Under the salinity higher than optimum salinity (higher than optimal situation), surfactant is mainly dispensed in oil.
Petroleum soap comes from naturally occurring petroleum acids, they by add alkali as NaOH or sodium carbonate improve salt solution basicity (pH) and by saponification.But thisly have a mind to saponification and raise (na concn) with salinity unintentionally and combine the environment of the petroleum soap likely making generation higher than optimum, namely reduce in oil-water interfacial tension effective not.This interdepend mean simple alkali drive may be difficult to control.On the other hand, the surfactant of production can regulate for required optimum salinity.Although come from industrial chemistry synthesis, these molecules are obviously higher than petroleum soap cost, because the latter only needs the cost injecting alkali.In addition, the main loss mechanism of the surfactant of production is adsorbed onto on storage layer rock.
The known surfactant mixture with different optimum salinity shows the optimum salinity of combination, and the optimum salinity of this combination follows the mixed principle of simple concentration decision.Utilize this extra degree of freedom, can design ASP preparaton, this design utilizes the potential (if present) of petroleum soap, simultaneously by selecting the surfactant produced to ensure optimum phase behavior.As additional benefit, the existence of alkali reduces the surfactant of production by the tendency of adsorbing, thus reduces the requirement of this valuable components.
The optimum salinity behavior of independent petroleum soap can be determined by tube assay, and wherein oil and salt solution mix in varing proportions, and alkali adds with the concentration of change subsequently.A set of such test tube provides in Figure 5, can infer that the optimum salinity of the petroleum soap of selective crude is about 0.22mol/l Na by it +.Carry out independent but similar analysis for the surfactant mixture for the production selected by this selective crude, result value is 0.76mol/l Na +.Fig. 6 gives the alkali scanning that 50/50 application oil and salt solution by volume carry out.Saline bag is containing the surfactant mixture of the production of 0.3wt%.Based at 1.25wt%Na 2cO 3there is large emulsion phase under concentration, can infer that the optimum salinity of the combination of surfactant and petroleum soap is 0.31mol/l Na +, namely between the respective value of surfactant mixture of petroleum soap and production.
Core oil displacement experiment
After demonstrating optimum phase behavior, in core oil displacement experiment, test ASP preparaton to prove the ability of its release and mobile irreducible oil.These experiments provide the information of the displacement stability of relevant chemical component characterization of adsorption and (inside) polymer flooding.It is 5cm and the long core oil displacement experiment data for the earth's surface sandstone core of 30cm is implemented that Fig. 7 to Fig. 9 gives at diameter.Displacement of reservoir oil order is as follows in this experiment: 2.2PV water drive; 0.3PV ASP drives; 2.6PV polymer flooding.Surfactant, 1wt%Na that ASP preparaton is produced by 0.3wt% 2cO 3form with the polymer solution of 27mPa.s.Polymer flooding also has the viscosity of 27mPa.s.
Injection pump pressure and effluent oil cut and the factor of gathering provide in the figure 7, wherein clearly show that the oil band when injecting 2.6PV-3.4PV is gathered, at the end of, the initial existence oil of 98% is gathered.By this with carbonate-bicarbonate effluent mobility and pH (Fig. 8) and effluent surfactant concentration and viscosity (Fig. 9) compare, although result shows that first half section that this oil is with is as the exploitation of " only " oil, the second half section is emulsified and containing ASP chemicals.Carbonate is converted into supercarbonate, and the magnesium hydrogen salt concentration when about 3PV (Fig. 8) is observed in this conversion corresponding temporarily to be increased, and this allows people expect in porous medium, there occurs two kinds of chemical processes: the saponification of petroleum acids and clay exchange.In this simulation, these are reacted by following group and represent:
1. carbonate-bicarbonate balance:
2. petroleum acids (HA o) saponification is soap (A -):
3. sodium exchanges clay hydrogen bonding:
This group reaction is considered to enough, unless the behavior under pH value is lower than 8 must accurately copy, then needs is comprised carbonic acid dissociation reaction, if or the salt water hardness (i.e. Ca 2+and Mg 2+concentration) enough large to such an extent as to deposit carbon hydrochlorate.
The surfactant concentration (Fig. 9) of effluent allows the breakthrough time determination surfactant adsorption characteristic by surfactant.For this operating mode, find the maximal absorptive capacity (amount of surfactant of unit quantity porous medium) being low to moderate 2 μ g/g, the ground watch core that this representative is very clean.This analogy model does not copy the magnitude of testing the effluent surfactant concentration determined.This is probably due to the following fact: namely only measure water ballast surfactant, and the expection of the surfactant of major part produces in emulsion or oil phase.But our simulation does not have simulated emulsion phase, but apply the phase behavior of simplification: optimum salinity (with reference to Figure 11) is calculated by thermodynamics mixing rule by following formula:
p opt(R)＝p A 1/(1+1/R)p s 1/(1+R)
Wherein p optrepresent optimum salinity, it is as petroleum soap (p a) and surfactant (p s) the function of respective optimum salinity, and ratio R=(molal quantity of soap)/(molal quantity of surfactant).Suppose that the oil-water partition coefficient of petroleum soap and surfactant follows the law of exponent as Types Below subsequently:
K ( p , R ) = ( p p opt ( R ) ) 6
It has imitated the funtcional relationship proposed by (Liu etc., 2006) such as Liu.It satisfies condition K (P opt(R), R)=1, namely under optimum salinity between You Heshui mean allocation (with reference to Figure 12).
Lab scale
Although say in principle and to understand very well in laboratory, about the enforcement of ASP still exists obvious uncertainty in oil field.After successful core oil displacement experiment, implement the test of a series of single well chemical tracer, to verify and to confirm the validity of ASP preparaton selected by underground at three oil fields (two sandstone, a carbonate).Meanwhile, the target for pattern displacement of reservoir oil ASP lab scale and design has been developed.Carry out injection pressure, fluid flow and effluent concentration that computer simulation constructs to predict different lab scale.
A series of single well chemical tracer test
Single well chemical tracer test (SWCT) provides determines by the volume extending into storage several meters, layer beyond wellhole the means that fixing oil is saturated.In fact, during SWCT, using a kind of chemical tracer as determining in slug Injection Well, and original position starts reaction and becomes another kind of chemical tracer subsequently.The chemicals that the chemicals injected and original position produce has different partition characteristics and therefore depends on the different conversion characteristics that major oil is saturated.Therefore, after of short duration withholding period, after injection slug resumes production, they arrive at different time.Irreducible oil is obtained to the explanation of the effluent concentration curve that they obtain saturated.
Ideally, each concentration curve shows single maximal value.It is saturated that separation between the maximal value of two curves relates to the irreducible oil represented by clear and definite analytic expression.May be because following reason causes with departing from of this ideal state, such as poor well globality or between withholding period any underground of chemicals slug reset, such as wellhole cross-flow or fluid drift.Therefore, such as good well globality and Duan Dan district pitch of holes are comprised for the choice criteria of well implementing SWCT and with the safe distance of active well with avoiding any interference.
In fact, apply the existing producing well with high water content may mean and can not meet all choice criteria equally well.The storage layer of well that Figure 13 gives in the PDO sandstone storage layer tested by SWCT describes daily record.The same with other alternative well of great majority in this considered oil field, the feature of selected well is the coated silk screen complete interval of 30m probeing into multiple storage layer.The pressure recorded during SWCT and data on flows and effluent tracer concentration curve provide respectively in figures 14 and 15.Figure 14 gives and respectively flows the period during SWCT: 3000m 3be that exploitation is removed in short hole after water drive; 30m 3containing 1wt% ethyl formate (EtF) as inject chemical tracer and 0.5wt% n-propanol (NPA) to mark the chemical tracer slug of this slug; 120m 3water slug, chemicals is driven to from wellhole 3m by this water slug; Two days stop doing business the phase, EtF partial hydrolysis forms ethanol (EtOH) during this period; 1.2 days resume production the phase.In addition, 30m 3and 120m 3slug all use 0.25wt% methyl alcohol (MeOH) to mark.The pan of the effluent tracer concentration curve shown in Figure 15 is disclosed and obviously the departing from of above-mentioned ideal state.The storage layer simulation comprising chemical tracer reaction conveying model shows, is the main cause of viewed effect by the cross-flow of three independent geology interlayers of wellhole.In the stopping PLT running early stage, unconspicuous this cross-flow is the result injecting stage each layer dynamic pressurized at tracer agent: total compressibility is lower and scope that is layer is less, then faster in injection its mean pressure increase of stage.This may cause the average pressure reduction of across-layer rest period by wellhole cross-flow rapid equalisation.For the particular case of three layer model discussed above, cross-flow needs the coupling reached shown in Figure 15: the outer about 10m of the layer that 6.5m is thick 3amount, and the outer 4m of the thick layer of 5.0m 3amount, both all enter the thick layer of top 13.5m (with reference to Figure 13).Residual oil saturation in the layer of 13.5m is 34%, and is 20% in other is two-layer, and the optimum digital water transfer obtained corresponds to bulk averaged value 28%, and this is consistent with the expection for this storage layer.
After this initial " baseline " SWCT, Xiang Jingzhong injects 420m 3predetermined ASP preparaton, carries out 60m subsequently 3tapered polymer drive and 420m 3water drive.Subsequently, in identical well, implement second time SWCT, to measure residual oil saturation, and evaluate the efficiency of ASP preparaton thus.It is believed that this experiment obtains the residual oil saturation (uncertain region is 0-6%) of 1%.This almost solution completely saturatedly meets completely with the core displacement of reservoir oil result of experiment, shows that storage layer condition has obtained in the lab suitably and copies.
To program like five well implementation of class altogether in three different oil fields, be namely first baseline SWCT, then inject the stage for ASP and be then another SWCT.The first two in these wells is positioned at the high-quality sandstone storage layer of relative heavy oil; Another two well locations are in two Different Strata of middle innage quality sandstone storage layer; 5th well location is in the carbonate storage layer of densification.In the same formation of target in identical oil field and phase mutual edge distance only has in the first two well of 430m, second well receives less ASP slug (44m 3), follow by polymer flooding (131m 3), the short tapered polymer displacement of reservoir oil (20m 3) and last long water drive (830m 3).Although the baseline SWCT of this second well causes the residual oil saturation (25%) similar with the first well, it is believed that final SWCT obtains the oil saturation of 23%.Although ASP slug obviously shortens, from experiment core displacement of reservoir oil result, the solution of this obvious deficiency is saturated still very unexpected.But before more deep analysis, can not compellently be that the unevenness of local storage layer and the fluid substitution of instability cause water-based chemistry tracer agent slug to penetrate through full-bodied ASP slug and polymer flooding, thus in fact SWCT produce the original residual oil saturation that can reach significantly more than ASP process again.Dilution alkali is produced and polymkeric substance supports this hypothesis while recording between chemical tracer slug payback period.Therefore, can judge that this SWCT technology is not suitable for determining the efficiency of small-sized (industrial scale) EOR process, this experience merits attention concerning experimental design subsequently.Still need to carry out interpretation of result to the latter.
Pattern oil displacement experiment
Although single well chemical tracer experimentalists and technicians provide the selected ASP preparaton of evidence saturated validity separated by to(for) underground, it does not confirm the durability of described ASP method in typical displacement of reservoir oil application by design: the stability of chemicals in underground duration of in the whole pattern displacement of reservoir oil; The formation of oil band and stable displacement thereof; Be subject to the impact of storage layer unevenness; The maximum sustainable injection flow of ASP slug and polymer flooding under condition is being split without uncontrollable storage lamination; The optimum industry volume of these slugs.Except the uncertainty that these are relevant to underground, still there is very large challenge in the design for ground ASP injecting scheme: close to withdrawal well and the formation at production equipment place carbonate scale or silicon dioxide dirt; In the exploitation of low-down oil water interfacial tension lactogenesis carburetion; The supply chain of involved chemicals and process.
The main standard of this work is: maximum data obtains as oil water suction, separates the saturated and factor of gathering; To the tolerance of well or equipment failure; The quantification that emulsification and dirt are formed and alleviating; Representational geology is arranged; The feasible lab scale duration.The risk confirmed comprises near producing well by ASP Pollution by Chemicals and uncontrollable pressure break.
Based on the above, the length of side is that five dot patterns that reverse (a center Injection Well is surrounded by four summit producing wells) of 75m × 75m are considered to best half measure.In addition, if needed, this pattern allows by summit producing well being converted into Injection Well and drilling out four new summit producing wells around the larger distance of original lab scale pattern, lab scale being expanded to larger schema size.Apply by the calibrated storage layer analogy model of above-mentioned core oil displacement experiment, carefully formatted oil field model by existing " history-coupling " and carried out ASP prognosis modelling.Injection and production flow results are shown in Figure 16, and the effluent concentration curve of expection is shown in Figure 10.Total duration is 1.5 years, spend about half a year in ASP injection and polymer flooding, and excess time is used for the water drive stage subsequently.After the lab scale operation of a year, the generation of oil band completes substantially.Assuming that after chemicals penetrates and occur in 0.3-0.4, then expection part oil band will with emulsified state extraction, although the relative concentration of surfactant is less.This is owing to there is production diluted stream in single five dot patterns that reverse, and this ASP for oil field scope implement and be not true to type.
Exemplary:
In one embodiment of the invention, disclose and a kind ofly to produce oil and/or the method for gas from subsurface formations, comprising: in subsurface formations, locate suitable storage layer; Set up storage layer model; Use laboratory data loaded with dielectric; Simulation storage layer is to determine based on the fluid substitution of injected fluid with the fluid produced; The optimum fluid mixture of fluid to be implanted is determined based on a series of sensitivity analysis carried out with model; Drill the first well in the earth formation; Optimum fluid mixture is injected in the first well; Drill the second well in the earth formation; Produce oil and/or gas with by the second well.In some embodiments, the first well is at a distance of 25 meters-1 kilometer, the second well.In some embodiments, optimum fluid mixture comprises water, surfactant, polymkeric substance and alkali.In some embodiments, described method is also included in the mechanism of injecting water-based mixture in the backward stratum optimum fluid mixture being released into stratum.In some embodiments, the optimum salinity determining surfactant in optimum fluid mixture is also comprised with laboratory data loaded with dielectric.In some embodiments, the optimum salinity determining to be reacted the soap formed by the alkali in optimum fluid mixture and the oil in stratum is also comprised with laboratory data loaded with dielectric.In some embodiments, drill the first well and also comprise probing and comprise the first well array of 5-500 mouth well, and wherein drill the second well and also comprise the second well array that probing comprises 5-500 mouth well.In some embodiments, the viscosity of optimum fluid mixture is determined with the laboratory data loaded with dielectric volume also comprised based on the polymkeric substance added in potpourri.In some embodiments, described method is also included in the optimum fluid mixture of the forward slip value injecting potpourri.In some embodiments, before the optimum fluid mixture of injection, described subsurface formations comprises the oil that viscosity is 0.5-250 centipoise.In some embodiments, the first well comprises ASP potpourri curve in the earth formation, and the second well comprises oil recovery curve in the earth formation, and described method also comprises overlapping with between oil recovery curve of ASP potpourri curve.In some embodiments, also comprise with the core product enforcement core oil displacement experiment comprising formation oil from stratum with laboratory data loaded with dielectric.In some embodiments, implement a series of sensitivity analysis with model and comprise often kind of component in change potpourri and the optimal value determining described often kind of component.In some embodiments, the oil in stratum has the first viscosity, and optimum fluid mixture has second viscosity, and the first viscosity is within 75 centipoises of second viscosity.In some embodiments, the oil in stratum has the first viscosity, and optimum fluid mixture has second viscosity, and second viscosity is the about 25-200% of the first viscosity.In some embodiments, the second well produces optimum fluid mixture and oily and/or gas.In some embodiments, if described method also comprises reclaim the optimum fluid mixture existed from oil and/or gas, and then optional optimum fluid mixture reclaimed at least partially to be refilled in stratum.In some embodiments, the injection pressure ratio of optimum fluid mixture injects the initial storage stressor layer height 0-37 of the pre-test of beginning, 000kPa.In some embodiments, subsurface formations has the perviousness of 0.0001-15 darcy, such as the perviousness of 0.001-1 darcy.In some embodiments, described method also comprises oil gathered at least partially and/or cyclostrophic to turn to and is selected from following material: transport fuel is as gasoline and diesel oil, heater oil, lubricant, chemicals and/or polymkeric substance.
Those skilled in the art will be understood that, when not departing from its essence and scope, may have multiple improvement and change for disclosed embodiment of the present invention, structure, materials and methods.Therefore, hereafter the scope of claims and functional equivalent thereof should not limit, because they are just exemplary in itself by particular that is disclosed and that describe here.

Claims (19)

1. produce oil and/or the method for gas from subsurface formations, comprising: in subsurface formations, locate suitable storage layer; Set up storage layer model; Use laboratory data loaded with dielectric; Simulation storage layer is to determine based on the fluid substitution of injected fluid with the fluid produced; The optimum fluid mixture of fluid to be implanted is determined based on a series of sensitivity analysis carried out with model; Drill the first well in the earth formation; Optimum fluid mixture is injected in the first well; Drill the second well in the earth formation; Produce oil and/or gas with by the second well, wherein the first well comprises ASP potpourri curve in the earth formation, and the second well comprises oil recovery curve in the earth formation, and described method also comprises overlapping with between oil recovery curve of ASP potpourri curve.
2. the process of claim 1 wherein that the first well is at a distance of 25 meters-1 kilometer, the second well.
3. the method for claim 1 or 2, wherein optimum fluid mixture comprises water, surfactant, polymkeric substance and alkali.
4. the method for claim 1 or 2, is also included in the mechanism of injecting water-based mixture in the backward stratum optimum fluid mixture being released into stratum.
5. the method for claim 1 or 2, wherein also comprises the optimum salinity determining surfactant in optimum fluid mixture with laboratory data loaded with dielectric.
6. the method for claim 1 or 2, wherein also comprises the optimum salinity determining to be reacted the soap formed by the alkali in optimum fluid mixture and the oil in stratum with laboratory data loaded with dielectric.
7. the method for claim 1 or 2, wherein drills the first well and also comprises probing and comprise the first well array of 5-500 mouth well, and wherein drills the second well and also comprise the second well array that probing comprises 5-500 mouth well.
8. the method for claim 1 or 2, wherein determines the viscosity of optimum fluid mixture with the laboratory data loaded with dielectric volume also comprised based on the polymkeric substance added in potpourri.
9. the method for claim 1 or 2, is also included in the optimum fluid mixture of the forward slip value injecting potpourri.
10. the method for claim 1 or 2, wherein before the optimum fluid mixture of injection, described subsurface formations comprises the oil that viscosity is 0.5-250 centipoise.
The method of 11. claims 1 or 2, wherein also comprises with laboratory data loaded with dielectric and implements core oil displacement experiment with the core product comprising formation oil from stratum.
The method of 12. claims 11, wherein implements a series of sensitivity analysis with model and comprises often kind of component in change potpourri and the optimal value determining described often kind of component.
The method of 13. claims 1 or 2, the oil wherein in stratum has the first viscosity, and optimum fluid mixture has second viscosity, and the first viscosity is within 75 centipoises of second viscosity.
The method of 14. claims 1 or 2, the oil wherein in stratum has the first viscosity, and optimum fluid mixture has second viscosity, and second viscosity is the 25-200% of the first viscosity.
The method of 15. claims 1 or 2, wherein the second well produces optimum fluid mixture and oily and/or gas.
The method of 16. claims 1 or 2, reclaims the optimum fluid mixture existed if also comprised, and then optionally to be refilled in stratum by optimum fluid mixture reclaimed at least partially from oil and/or gas.
The method of 17. claims 1 or 2, wherein the injection pressure ratio of optimum fluid mixture injects the initial storage stressor layer height 0-37 of the pre-test of beginning, 000kPa.
The method of 18. claims 1 or 2, wherein subsurface formations has the perviousness of 0.0001-15 darcy.
The method of 19. claims 1 or 2, also comprises oil gathered at least partially and/or cyclostrophic to turn to and is selected from following material: transport fuel, heater oil, lubricant, chemicals and/or polymkeric substance.
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