CN102763118A - Systems and methods for producing oil and/or gas - Google Patents
Systems and methods for producing oil and/or gas Download PDFInfo
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- CN102763118A CN102763118A CN2011800103055A CN201180010305A CN102763118A CN 102763118 A CN102763118 A CN 102763118A CN 2011800103055 A CN2011800103055 A CN 2011800103055A CN 201180010305 A CN201180010305 A CN 201180010305A CN 102763118 A CN102763118 A CN 102763118A
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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
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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
- 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
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- 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
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- 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
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
Technical field
The present invention relates to 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.The EOR that has three kinds of main types, instant heating, chemicals/polymkeric substance and gas inject, and they can be used to increase the oil recovery of storage layer, make it to surpass the petroleum production that classic method possibly reach, thereby might prolong oilfield life and improve oil recovery.
Hot enhanced recovery works through the storage layer is heated.The form of widespread use is a steam flood, thereby it has reduced oil viscosity oil and can flow to producing well.The chemical displacement of reservoir oil holds back the capillary force of Residual oil through reduction and/or the interfacial tension between reduction oil and the water increases oil recovery.Polymer flooding improves the displacement sweep efficiency that injects water.Ratio oil itself flows to the injectant of producing well more easily and the potpourri of oil works through producing but immiscible material injects.
With reference to figure 1, prior art system 100 has been described wherein.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 passes stratum 102 and 104 and end at stratum 106.Part stratum 106 is represented at 114 places.Oil is gentle to be produced to production facility 110 through well 112 by ground layer segment 114.Gas separates with liquid state each other, and gas is stored in gas bunkerage 116 neutralising fluids and is stored in the liquid storage equipment 118.
U.S. Pat 6; 022; 834 disclose a kind of concentrated surfactant preparaton and from the gather method of Residual oil of oilbearing stratum; More specifically be a kind of basic surface activating agent displacement of reservoir oil method, this method can cause interfacial tension ultralow between injecting material and the Residual oil, and wherein said concentrated surfactant preparaton is higher than, is equal to or less than in concentration under its CMC concentration to be supplied with; Said patent also provides through the reaction original position between the basic matterial of naturally occurring organic acidity component and injection and has formed surface active material, and said surface active material is used for increasing oil-production efficiency.U.S. Pat 6,022,834 are incorporated herein by reference at this in full.
U.S. Pat 5; 068; 043 discloses a kind of being used for drives method from the aqueous bases of the storage layer recovery of oil that contain acid-soluble oil, and said method comprises the preformed cosurfactant material that adds the excessive basic matterial of stoichiometry and certain kind and quantity to the alkaline aqueous solution that injects, and the latter will increase the salinity of said solution; Thereby with storage layer in oil when contact, the requirement of formation salinity can be minimized the surfactant system of interfacial tension between itself and the oil.U.S. Pat 5,068,043 is incorporated herein by reference at this in full.
The open US 2009/0194276 of U.S. Patent application that is disclosed on August 6th, 2009 discloses the system and method for optimum salinity type of definite surfactant microemulsion system and optimum salinity.The optimum salinity type of surfactant/polymer flooding and optimum salinity confirmed by the core oil displacement experiment, thereby a plurality of polyphasic flow parameter will influence the definite of optimum salinity type and optimum salinity like the relative permeability that influence oil recovery with holding back mutually etc.Determined optimum salinity is preferably corresponding to the highest oil recovery.The open US of U.S. Patent application 2009/0194276 is incorporated herein by reference at this in full.
The open US 2009/0194281 of U.S. Patent application that is disclosed on August 6th, 2009 discloses the optimum salinity curve that in the surfactant/polymer flooding by the displacement of reservoir oil of local water post-flush, causes the maximum oil recovery ratio.The optimum salinity of being confirmed by the core oil displacement experiment can be used for surfactant slug.Before injecting a surfactant slug to storage layer with inject buffer plug afterwards immediately and deterioration do not take place with the protection surfactant slug, wherein said buffer plug has the salinity identical or roughly the same with surfactant slug.Lower salinity can be used for the post-flush displacement of reservoir oil, and local water can be any salinity.The open US2009/0194281 of U.S. Patent application is incorporated herein by reference at this in full.
The improvement system and method that needs enhanced oil recovery in this area.The improvement system and method that also needs using basic surfactant polymer (ASP) displacement of reservoir oil in this area, for example the viscosity through increasing injectant, reduce interfacial tension between injectant and the oil, utilize injectant and oil to form emulsion and/or other chemical effect is carried out.The improvement system and method that also needs the ASP displacement of reservoir oil in this area.
Summary of the invention
In one aspect, the present invention provides a kind of and produces oil and/or the method for gas from subsurface formations, and said method comprises: the suitable storage layer in location in subsurface formations; Set up the storage layer model; Fill model with laboratory data; Simulation storage layer is to confirm based on the fluid displacement of the fluid that is injected with the fluid that is produced; Confirm to be used to wait to inject the optimum fluid mixture of fluid based on a series of sensitivity analysis of carrying out with model; Probing first well in the stratum; In first well, inject optimum fluid mixture; Probing second well in the stratum; With produce oil and/or gas by second well.
Advantage of the present invention comprises one or more as follows:
Strengthen the improvement system and method that the stratum hydrocarbon is gathered with the ASP displacement of reservoir oil.
The improvement system and method for gathering with the hydroenhancement stratum hydrocarbon that contains the ASP displacement of reservoir oil.
Be used for improvement composition and/or technology that secondary and/or three hydrocarbon are gathered.
The improvement system and method that is used for enhanced oil recovery.
The improvement system and method for the enhanced oil recovery of the application of ASP displacement of reservoir oil.
Application and the improvement system and method for water than the enhanced oil recovery of the compound of the interfacial tension of viscosity with increase and reduction.
Description of drawings
Fig. 1 has described the production system of oil and/or gas.
Fig. 2 a has described the distribution of well.
Fig. 2 b and 2c have described the distribution of the well of Fig. 2 a in enhanced oil recovery processes.
Fig. 3 has described oil and/or gas production system.
Fig. 4 describes the distribution of well.
Fig. 5 has described the potpourri of crude oil and salt solution.
Fig. 6 has described the potpourri of crude oil and salt solution.
Fig. 7 has described the result of core oil displacement experiment.
Fig. 8 has described the result of core oil displacement experiment.
Fig. 9 has described the result of core oil displacement experiment.
Figure 10 has described the simulation of the lab scale ASP displacement of reservoir oil.
Figure 11 has described the relation between the optimum salinity of optimum salinity and soap of surfactant.
It is the distribution of benchmark soap and surfactant that Figure 12 has described with the salinity.
Figure 13 has described the result of well daily record.
Figure 14 has described the oil field data of single well chemical tracer test.
Figure 15 has described the oil field data of single well chemical tracer test.
Figure 16 has described the simulation of the lab scale ASP displacement of reservoir oil.
Embodiment
Accompanying drawing 2a:
With reference to accompanying drawing 2a, well array 200 has in some embodiments been described wherein below.Array 200 comprises well group 202 (being represented by horizontal line) and well group 204 (being represented by oblique line).
Each well in the well group 202 and the adjacent well in the well group 202 have horizontal range 230.Each well in the well group 202 and the adjacent well in the well group 202 have vertical range 232.
Each well in the well group 204 and the adjacent well in the well group 204 have horizontal range 236.Each well in the well group 204 and the adjacent well in the well group 204 have vertical range 238.
Shown in Fig. 2 a, horizontal range 230 and horizontal range 236 all refer on the paper distance from left to right, and vertical range 232 and vertical range 238 all refer on the paper distance from top to bottom.In fact, array can by perpendicular to the perpendicular hole on the face of land, be parallel to the horizontal well on the face of land or with respect to the face of land with the for example 30-60 degree well construction of tilting of some other angles.
Each well in the well group 202 and the distance between the adjacent well in the well group 204 are 234.Each well in the well group 204 and the distance between the adjacent well in the well group 202 are 234.
In some embodiments, each well in the well group 202 is surrounded by four wells in the well group 204.In some embodiments, each well in the well group 204 is surrounded by four wells in the 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, for example in well group 202, have an appointment the 5-500 mouth well and the 5-500 mouth well of in well group 204, having an appointment.Randomly, about 2-1000 mouth plugged well 250 can be provided, for example 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 the stratum and the cross sectional side view of well group 204.
Can accomplish through 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 being used for from the method for subsurface formations recovery of oil and/or gas is not crucial.
In some embodiments, can realize through any known method with plugged well 250 shutoff oil and/or gas and/or enhanced oil recovery reagent.Suitable method comprises pumps water, steam, the primitive water that is produced, seawater, carbon dioxide, rock gas or other gaseous state or liquid hydrocarbon, nitrogen, air, salt solution or other liquid or gas in plugged well 250.In another embodiment, plugged well 250 can be used for forming and freeze obstacle.In U.S. Pat 7,225, a kind of suitable obstacle that freezes is disclosed in 866, this patent is incorporated herein by reference at this in full.For not crucial with the selection of plugged well 250 shutoff oil and/or gas and/or the employed method of enhanced oil recovery reagent.
In some embodiments, oil and/or gas can be from well be gathered on the stratum, and flow through well and flowline gets in the facility.In some embodiments, utilize the ASP potpourri for example the enhanced oil recovery of water, alkali, surfactant and mixture of polymers can be used for strengthening oil and/or gas flowing from the stratum.
Accompanying drawing 2b:
With reference to accompanying drawing 2b, well array 200 has in some embodiments been described wherein below.Array 200 comprises well group 202 (representing with horizontal line) and well group 204 (being represented by oblique line).Around well array 200 optional plugged well 250 is provided.
In some embodiments, in well group 204, inject ASP potpourri and from well group 202 recovery of oil.As shown in the figure, the ASP potpourri has the curve 208 of injection, and in well group 202, produces oil recovery curve 206.In some embodiments, in plugged well 250, inject shutoff reagent.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 gets into output well group 202.
In some embodiments, the ASP potpourri injects well group 202 and by well group 204 recovery of oil.As shown in the figure, the ASP potpourri has the curve 206 of injection, 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 gets into output well group 204.
In some embodiments, well group 202 can be used to inject the ASP potpourri and well group 204 can be used in very first time section, produced oil and/or gas by the stratum; Well group 204 can be used to inject the ASP potpourri and well group 202 can be used in second time period, produced oil and/or gas by the stratum then, and first and second time periods formed one-period.
In some embodiments, ASP potpourri or the potpourri that comprises the ASP potpourri can inject and when end cycle, can inject the optional water that is added with polymkeric substance and get into producing well to promote the ASP potpourri when the cycle begins.In some embodiments, the incipient stage in cycle is can be for the initial 10-in cycle about 80%, or the initial 20-in cycle is about 60%, and the initial 25-in cycle is about 40%, and the end cycle period is the remainder in cycle.
In some embodiments, the optional water that is added with polymkeric substance can be used as shutoff reagent and be injected in the plugged well 250.
In some embodiments, the ASP potpourri that is injected into the stratum can reclaim from the oil of extraction and/or gas, and re-injects in the stratum.
In some embodiments, the oil viscosity that before any enhanced oil recovery reagent of injection, exists on the stratum 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, be about 125 centipoises at the most injecting the oil viscosity that exists on the stratum before any enhanced oil recovery reagent, or about at the most 200 centipoises, or about at the most 500 centipoises, or about at the most 1000 centipoises.
Accompanying drawing 2c:
With reference to accompanying drawing 2c, well array 200 has in some embodiments been described wherein below.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, it is overlapping 210 that the injection curve of ASP potpourri 208 and oil recovery curve 206 have, and oil recovery curve 206 produces to well group 202.In some embodiments, in plugged well 250, inject shutoff reagent.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 gets into output well group 202.Through after the time enough section, shutoff reagent inject curve can with inject the one or more overlapping of curve 208 and oil recovery curve 206, thereby enhanced oil recovery reagent by shutoff in array 200; And/or oil and/or sealing gland are got lodged in the 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, it is overlapping 210 that the injection curve of ASP potpourri 206 and oil recovery curve 208 have, and oil recovery curve 208 produces to well group 204.In some embodiments, in plugged well 250, inject shutoff reagent.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 gets into output well group 204.Through after the time enough section, shutoff reagent inject curve can with inject the one or more overlapping of curve 208 and oil recovery curve 206, thereby enhanced oil recovery reagent by shutoff in array 200; And/or oil and/or sealing gland are got lodged in the array 200; And/or make shutoff reagent output to well group 204.
Discharging at least a portion ASP potpourri and/or other liquid and/or gas can realize through any known method.A kind of suitable method is in first well, to inject the ASP potpourri and go out at least a portion ASP potpourri through second well with said gas and/or liquid pumping.Selection for the method that is used for injecting at least a portion ASP potpourri and/or other liquid and/or gas is not crucial.
In some embodiments, can be under ASP potpourri and/or other liquid and/or gas pump be sent into the stratum up to the pressure of stratafrac pressure.
In some embodiments, the ASP potpourri can mix the potpourri that can be gathered by well to form with oil in the stratum and/or gas.
In some embodiments, can a certain amount of ASP potpourri be injected well, inject another component subsequently and pass the stratum to order about the ASP potpourri.For example, for the water of liquid state or gaseous form, contain dissolved polymers and can be used to order about the ASP potpourri with water, carbon dioxide, other gas, other liquid and/or their potpourri that increases its viscosity and pass the stratum.
In some embodiments, can inject the ASP potpourri of about 0.1-5 pore volume, for example can inject the ASP potpourri of about 0.2-2 pore volume or about 0.3-1 pore volume.After injecting, can then inject in the ASP potpourri polymer water potpourri of about 2-10 pore volume, the polymer water potpourri of for example about 3-8 pore volume.After injecting, can then inject in the polymer water potpourri water of about 1-10 pore volume.
Accompanying drawing 3:
With reference to accompanying drawing 3, system 400 has in some embodiments of the present invention been described wherein below.System 400 comprises subsurface formations 402, stratum 404, stratum 406 and stratum 408.Production facility 410 is provided on the ground.Well 412 passes stratum 402 and 404, and there is perforate at 406 places on the stratum.Part stratum 414 can be chosen pressure break and/or perforate wantonly.When oil gentle during by stratum 406 outputs, their entering parts 414 and along being advanced into production facility 410 on the well 412.Can and can gas be delivered in the gas bunkerage 416 and with liquid and deliver in the liquid bunkerage 418 gas and fluid separation applications.Production facility 410 can mix, produces and/or store the ASP potpourri, and the ASP potpourri can produce in production/bunkerage 430 and store.
The ASP potpourri pumps into well 432 downwards, 406 the part 434 to the stratum.It is gentle with supplement production oil that the ASP potpourri passes stratum 406, and whole output to the well 412 of ASP potpourri, oil and/or gas arrives production facility 410 then.The ASP potpourri can circulate then, for example through using oil-water gravity separator, hydro-extractor, emulsion breaker, boiling, condensation, filtration and other separation method well known in the prior art, then the ASP potpourri is refilled in the well 432.
Plugged well 450 that has injecting mechanism 452 and the plugged well 460 that has 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, like the refrigerant that produces freezing wall or liquid or gas such as water, the water that mixes with tackifier, the water that mixes with alkali, the water that mixes 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 that mixes with other component can be injected in the well 432; Then inject another kind of component and pass stratum 406, for example gaseous state or liquid water, the water that mixes with one or more salt, polymkeric substance, alkali and/or surfactant with the ASP potpourri that orders about the ASP potpourri or mix with other component; Carbon dioxide; Other gas; Other liquid; And/or their potpourri.
In one embodiment, can the ASP potpourri of the for example about 0.25-1 pore volume of about 0.1-2 be injected well 432.Viscosity that then will the for example about 1-5 pore volume of about 0.5-10 is about ASP mixture viscosity 25% and 10% injects well 432 with interior polymkeric substance-aqueous mixtures according to appointment with interior.Water that then will about 1-10 pore volume injects well 432.
In some embodiments, produce oil and/or the well of gas 412 for the representative of well in the well group 202 and the well 432 that is used for injecting the ASP potpourri are representatives of well group 204 wells.
In some embodiments, produce oil and/or the well 412 of gas is that the well 432 that the ASP potpourri is injected in the representative of well in the well group 204 and being used for is representatives of well group 202 wells.
Accompanying drawing 4:
Accompanying drawing 4 has been described the method 500 that design ASP drives.Method 500 comprises optimum salinity, the optimum salinity of confirming soap 504 of confirming surfactant 502, confirm since added polymkeric substance 506 mixture viscosity, set up the model 508, correlation model and the given data 510 that comprise stratum, chemicals and oily characteristic and application model and design ASP and drive 512 for ASP drives.Further details for each step is described below.
The ASP method is that two kinds of chemical displacement of reservoir oil technology early are that surfactant and polymer drives the combination of driving with alkali.In these methods, the task of the chemicals that is injected is dual: at first, reduce the oil that the interfacial tension between the profit is held back by capillary force with release; And next, when in case of necessity, stablize said displacement through the viscosity that adds polymkeric substance increase water.Under the situation that surfactant and polymer drives, the reduction of interfacial tension realizes through injecting surfactant.And under the situation that alkali drives, alkali (for example NaOH or Na
2CO
3Improved the pH value of salt solution, this can cause the oleic acid saponification of crude oil carrier band conversely, thereby original position produces the natural surfactant that is commonly referred to " soap ".
Though the surfactant (abbreviating " surfactant " hereinafter as) that injects is obviously different chemically with the surfactant (being called " soap ") that original position produces, they have unified performance, and promptly their interfacial activities depend on environment such as salinity.Except the constant outer condition, there is optimum salt salinity water, farthest reduced oil-water interfacial tension at this optimum salt salinity water lower surface activating agent or soap.
In low salinity (" being lower than optimum state ") or under than high salinity (" being higher than optimum state "), the reduction of interfacial tension is less.Be lower than under the optimum state, surfactant and soap help being dispensed into the salt water; Be higher than under the optimum state, they help being dispensed into oil phase; Only near their separately optimum salinity the time, they could produce the 3rd independent " micro emulsion phase ", all show extremely low interfacial tension between this and oil phase and the water.Optimum salinity is specific for surfactant; The optimum salinity of soap obviously will be lower than typical injection surfactant usually.
Can design the ASP potpourri make chemical slug optimum salinity near or equal to inject the actual salt salinity water of water, thereby realize low oil-water interfacial tension.High or low salinity will make surfactant or soap can not be pushed entering producing well (being lower than optimal situation) effectively or be assigned with and get in the fixing oil, promptly be retained in the oil, therefore lost (being higher than optimal situation).
The ASP potpourri can comprise alkali, surfactant and the polymkeric substance that injects together as a slug.In this slug, alkali and surfactant move with (a little) different speed usually: surfactant is dispensed into the neutralization of any irreducible oil and carries out matrix absorption, and alkali is through saponification, carbonate deposition with possibly be consumed with the matrix exchange reaction.
After injection, the phase behavior of ASP slug is lower than or near optimum state.Then, with after crude oil contacts, the saponification process has reduced produces the optimum salinity in soap zone, is higher than optimum state thereby local phase behavior is changed at alkali.The result has set up optimum salinity and has been higher than the optimum optimum gradient that is lower than to chemical slug rear end at chemical slug front end, and this gradient has limited chemical slug and limited and disperseed dilution.This intrinsic gradient can move optimum interfacial activity district thereby pass through the storage layer in principle through the expansion of storage layer, causes not having oil to be left.
Confirm the optimum salinity of surfactant phase:
In order to confirm the chemofacies behavior of surfactant, can use a series of samples, for example test tube with Different Alkali and common salt concentration.Such example is in zero alkali concn, shown in accompanying drawing 5, can be inferred the optimum salinity of pure surfactant solution by this sample.Can infer that the test tube that produces independent emulsion phase is in or near optimum salinity, thus interfacial tension be reduced to maximal value.
Confirm the optimum salinity of soap phase:
In order to confirm the chemofacies behavior of soap, basic according to the program identical, just a bit complicated with definite surfactant.Soap is the alkali or the reactor product of oxyhydroxide and oleic acid more specifically.Thereby the soap amount that produces depends on the alkali number that joins in the salt solution.
Also increase salinity but add alkali, therefore can not study the behavior under the low salinity with high soap concentration combination.When using sodium carbonate and making alkali, the simple form of the balanced reaction of control saponification is an aqueous reaction:
Na
2CO
3→ 2Na
++ CO
3 2-(formula 1)
And saponification:
(formula 3)
In formula 3, HA
oRepresent oil to carry acid, A
-Represent soap.Because HA
o+ OH
-Be present in respectively in oil and the water, according to understanding the generation at the interface that back one is reflected at oil and water.
" total acid number " that is decided by oil (TAN) promptly measured in the oil amount of the volumetric molar concentration of acid, needs the alkali of different amounts to realize fully saponified.Relatively carbonate can be illustrated in the saponification whether obvious degree has taken place in given oil and the saline mixture with the volumetric molar concentration of acid.
Confirm the viscosity of polymer solution:
For polymkeric substance of confirming the viscosity of polymer solution, the sample with different salinity is had to make an addition to given volume wherein and the viscosity of confirming sample then.Usually, increasing salinity will cause than low viscosity, and the volume of increase polymkeric substance will cause viscosity higher.
In one embodiment, the mobility ratio of ASP potpourri and the oil in stratum coupling.Usually, the ASP potpourri is the function of viscosity with the mobility ratio of oil.Therefore, in the ASP potpourri, add polymkeric substance seemingly up to the viscosity of this potpourri and oils.In one embodiment, the viscosity number of ASP potpourri the oil viscosity value 50% in, for example 20% with interior or in 10%.
Set up model:
In brief, model is the description of two phases (water and the oil) polycomponent (surfactant, acid, soap, polymkeric substance, contain water chemistries) of ASP method, comprises that the composition of salt water chemistry, chemicals relies on distribution, 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 the ASP potpourri of discussing above is to convert into and be lower than optimum behavior (rich surfactant district) by being higher than optimum behavior (Fu Zaoqu).Because the given position soap changes with the surfactant concentration ratio in the storage layer, therefore be necessary for optimum salinity.Surfactant and soap optimum salinity separately is as passing through the input parameter that experiment is confirmed.
Surfactant and soap all allow to distribute between water and oil as the function of topical chemicals concentration (phase composition).This distribution has determined flowing of surfactant and soap.The basis of apportion model is to be lower than optimum or to be higher than the optimal tables surface-active agent and soap distributes the qualitative observation in entry or the oil strongly along with partial groups becomes to be respectively.But at optimum salinity place, surfactant and soap distribute in entry and the oil with equal portions.Because ASP drives and possibly take the lead the surfactivity band and be higher than optimum and in said band, be lower than optimum, the true character of partition factor maybe be not too relevant.
In model, provide interfacial tension related.This association supposition obtains user-defined minimum interfacial tension at optimum salinity place.In addition, at high soap and surfactant concentration ratio place, owing to soap has been set up minimum interfacial tension.At last, if total surfactant concentration (being the summation of surfactant and soap concentration) for or be higher than critical micelle concentration, then can only realize minimum interfacial tension.When the total concentration of soap and surfactant reduced, interfacial tension moved closer to unadjusted oil-water number.
This model has Viscosity Model, has considered that wherein viscosity is to polymer quality mark in the water and the effectively dependence of salinity.
Saponification degree depends on local alkali concn.Therefore, follow the tracks of this concentration and to influence the acid that soap produces be the characteristic of ASP model with other component concentrations.Long for fear of simulated time, the number of reactant can be the least possible, comprises saponification equation described above.
The prediction that the complicacy of the ASP displacement of reservoir oil and ASP model and necessary model simplification require model to produce is effective.For this reason, can carry out the simulation of detailed one dimension, and with the chemicals of gained with produce curve and other model or other given data and compare.Subsequently, the ASP core of experiment drives data and can mate with historical data, so that model and said core drive the data association of generation.Site of deployment is tested and is further improved this model by the industrial scale data that the storage layer obtains then.
Design ASP potpourri
In case successfully designed model and be provided with parameter to given oil field or stratum, then this model can be used to confirm the component of ASP potpourri.Under the complicacy of given a plurality of parameters and composite chemical, suitable starting point possibly be the ASP potpourri chemistry that use the front, the optimum potpourri chemistry of discussing above perhaps using of being confirmed by laboratory experiment.Thus, the salinity of potpourri possibly change, and surfactant concentrations, the concentration of polymkeric substance and the concentration of alkali all possibly change simultaneously.Model possibly further demarcated by additional lab investigation and experiment, thus the suitably salinity of analog variation, surfactant concentration, polymer concentration and/or alkali concn.
In one embodiment, the sensitivity analysis that can at first accomplish surfactant concentration is carried out identical analysis to alkali subsequently, and then polymkeric substance is analyzed to realize optimum surfactant concentration.But order is not crucial.
Usually, the oil recovery of increase is compared with the cost of the chemicals that obtains optimum potpourri.
Replacement scheme:
In some embodiments, oil that is produced and/or gas can be delivered in refinery and/or the treatment facility.Can handling oil and/or gas with manufacture product such as transport fuel such as gasoline and diesel oil, heater oil, lubricant, chemicals and/or polymkeric substance.Processing can comprise that rectifying and/or the said oil of fractionation and/or gas are to produce one or more distillate cuts.In some embodiments, oil and/or gas and/or one or more distillate cut can experience following one or more methods: catalytic cracking, hydrocracking, hydrotreating, coking, thermal cracking, distillation, reformation, polymerization, isomerization, alkylation, blend and dewaxing.
Embodiment:
This route of actual lab scale is used for estimating and verifying the feasibility in large-scale sandstone storage layer ASP project to the oil field from design proper A SP preparaton.
Laboratory work and model calibration
Need a cover laboratory experiment to quantize the behavior of ASP preparaton.During beginning, the phase behavior of separate analysis surfactant mixture and polymer viscosity behavior.Subsequently, the two is made up in the core oil displacement experiment studying the oil recovery of given combination, and demarcate flow simulating and be used for predicting subsequently.
The phase behavior experiment
For this purpose, can think surfactant mixture by two kinds independently material form: the petroleum soap that the injection surfactant of being produced and original position produce.Have visibly different molecular structure though say the two in principle, they all have the ability (though under different salt salinity waters) that reduces interfacial tension between crude oil and the salt solution, suppose that all other macroscopic properties are by the decision of storage 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 that reaches optimum salinity conversely.With interfacial activity, surfactant depends on salinity in the distribution oily, that salt solution is alternate with emulsion: under optimum salinity, surfactant is dispensed into the emulsion phase; Under the salinity that is lower than optimum salinity (being lower than optimal situation), surfactant mainly is dispensed into salt solution; Be higher than under the optimum salinity salinity of (being higher than optimal situation), surfactant mainly is dispensed in the oil.
Petroleum soap comes from naturally occurring petroleum acids, they through add alkali such as NaOH or sodium carbonate improve salt solution basicity (pH) and by saponification.But thisly have a mind to saponification and the salinity unintentionally environment that (na concn) combine the petroleum soap that might make generation that raises and be higher than optimum, promptly reduce aspect the oil-water interfacial tension effective inadequately.This interdepend mean simple alkali drive possibly be difficult to control.On the other hand, the surfactant of production can be regulated to needed optimum salinity.Though it is synthetic to come from industrial chemistry, these molecules are obviously higher than petroleum soap cost, because the latter only need inject the cost of alkali.In addition, the main loss mechanism of the surfactant of production is to be adsorbed onto on the storage layer rock.
Known surfactant mixture with different optimal salinity shows the optimum salinity of combination, and the optimum salinity of this combination is followed the mixed principle of simple concentration decision.Utilize this extra degree of freedom, can design the ASP preparaton, this design utilizes the potential (if existence) of petroleum soap, guarantees optimum phase behavior through the surfactant of selecting to produce simultaneously.As additional benefit, the existence of alkali has reduced the tendency that the surfactant produced is adsorbed, thereby has reduced the requirement of this valuable components.
The optimum salinity behavior of independent petroleum soap can be confirmed that wherein oil is with salt solution mixes in varing proportions and the concentration adding of alkali to change subsequently by test tube experiment.The such test tube of one cover provides in Fig. 5, can infer that by it optimum salinity of the petroleum soap of selective crude is about 0.22mol/l Na
+Carry out independence but similarly analysis for the surfactant mixture to the selected production of this selective crude, result value is 0.76mol/l Na
+Fig. 6 has provided by volume and 50/50 has used alkali scanning oily and that salt solution carries out.Salt solution comprises the surfactant mixture of the production of 0.3wt%.Be based on 1.25wt%Na
2CO
3Have big emulsion phase under the concentration, the optimum salinity that can infer the combination of surfactant and petroleum soap is 0.31mol/l Na
+, promptly between the surfactant mixture value separately of petroleum soap and production.
The core oil displacement experiment
After having verified optimum phase behavior, test ASP preparaton is to prove the ability of its release and mobile irreducible oil in the core oil displacement experiment.These experiments provide the information of the displacement stability of relevant chemical composition characterization of adsorption and (inside) polymer flooding.It is 5cm and the core oil displacement experiment data of length for implementing on the face of land sandstone core of 30cm that Fig. 7 to Fig. 9 has provided at diameter.Displacement of reservoir oil order as follows in this experiment: the 2.2PV water drive; 0.3PV ASP drives; 2.6PV polymer flooding.Surfactant, 1wt%Na that the 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 provide in Fig. 7 with the factor of gathering, and clearly show that wherein the oil band when injecting 2.6PV-3.4PV is gathered, and when finishing, 98% initial existence oil is gathered.With this and carbonate-supercarbonate effluent mobility and pH (Fig. 8) and effluent surfactant concentration and viscosity (Fig. 9) relatively, though the result show should the oil band preceding half section conduct " only " oil exploit, the second half section is by emulsification and contain the ASP chemicals.Carbonate is converted into supercarbonate, and corresponding this conversion observes that magnesium hydrogen salt concentration temporarily increases when about 3PV (Fig. 8), and this lets the people expect in porous medium, taking place two kinds of chemical processes: the saponification of petroleum acids and clay exchange.In this simulation, these are represented by the reaction of following group:
1. carbonate-supercarbonate balance:
2. petroleum acids (HA
o) saponification is soap (A
-):
3. sodium exchanges the clay hydrogen bonding:
This group reaction is considered to enough, only if the behavior that is lower than under 8 in the pH value must accurately be duplicated, then needs is comprised the carbonic acid dissociation reaction, if perhaps the salt water hardness (is Ca
2+And Mg
2+Concentration) to such an extent as to enough big deposit carbon hydrochlorate.
The surfactant concentration of effluent (Fig. 9) allows to confirm through the breakthrough time of surfactant the characterization of adsorption of surfactant.For this operating mode, find to be low to moderate the maximal absorptive capacity (amount of surfactant of unit quantity porous medium) of 2 μ g/g, the ground watch core that this representative is very clean.This analogy model does not duplicate the magnitude of the definite effluent surfactant concentration of experiment.This probably is because following true: promptly only measured the water ballast surfactant, and the surfactant of major part is expected in emulsion or the oil phase and produces.But the emulsion phase is not simulated in our simulation, but has used the phase behavior of simplifying: optimum salinity (with reference to Figure 11) is pressed following formula and is calculated by the thermodynamics mixing rule:
p
opt(R)＝p
A 1/(1+1/R)p
s 1/(1+R)
P wherein
OptRepresent optimum salinity, it is as petroleum soap (p
A) and surfactant (p
s) the function of optimum salinity separately, and ratio R=(molal quantity of soap)/(molal quantity of surfactant).Suppose that subsequently the oil-water partition coefficient of petroleum soap and surfactant follows the law of exponent of following type:
It has imitated the funtcional relationship that is proposed by (Liu etc., 2006) such as Liu.Its K (P that satisfies condition
Opt(R), R)=1, promptly under optimum salinity between You Heshui mean allocation (with reference to Figure 12).
Lab scale
Though say fine understanding in the laboratory in principle, still there is tangible uncertainty in the enforcement of relevant ASP in the oil field.Behind the core oil displacement experiment of success, (two sandstone, a carbonate) has been implemented a series of single well chemical tracer tests in three oil fields, to verify and to confirm the validity at underground selected ASP preparaton.Simultaneously, developed target and the design that is used for pattern displacement of reservoir oil ASP lab scale.Carry out computer simulation to predict injection pressure, fluid flow and the effluent concentration of different lab scale structures.
A series of single well chemical tracer tests
Single well chemical tracer test (SWCT) provides by confirming the saturated means of fixed oils in the volume that extends into several meters on storage layer beyond the wellhole.In fact, during SWCT, with a kind of chemical tracer as definite slug inject well and subsequently original position begin reaction and become another kind of chemical tracer.The chemicals that is injected has different partition characteristics and therefore depends on the different conversion characteristics that major oil is saturated with the chemicals that original position produces.Therefore, after of short duration withholding period, after the injection slug resumed production, they arrived at different time.It is saturated that the explanation of the effluent concentration curve that they obtained is obtained irreducible oil.
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 of representing through clear and definite analytic expression.With departing from of this ideal state possibly be owing to following reason causes, for example poor well globality or in any underground rearrangement of stopping period chemicals slug, for example wellhole cross-flow or fluid drift.Therefore, for the choice criteria of the well of implementing SWCT comprise for example good well globality and short single district's pitch of holes and with the safe distance of active well with avoiding any interference.
In fact, using existing producing well with high water content possibly mean and can not satisfy all choice criteria equally well.Figure 13 has provided by the storage layer of the well in the PDO sandstone storage layer of SWCT test and has described daily record.The same with other alternative well of great majority in this oil field of being considered, the 30m that probes into a plurality of storage layers that is characterized as of selected well coats the silk screen complete interval.In Figure 14 and Figure 15, provide respectively in the pressure that writes down during the SWCT and data on flows and effluent tracer concentration curve.Figure 14 has provided each mobile period: 3000m during SWCT
3Remove exploitation for short hole after the water drive; 30m
3Contain 1wt% ethyl formate (EtF) as the chemical tracer that injects and 0.5wt% n-propanol (NPA) chemical tracer slug with this slug of mark; 120m
3The water slug, this water slug is driven to chemicals from wellhole 3m; Two days stop doing business the phase, the EtF partial hydrolysis forms ethanol (EtOH) during this period; 1.2 resuming production the phase of it.In addition, 30m
3And 120m
3Slug all use 0.25wt% methyl alcohol (MeOH) mark.The pan of the effluent tracer concentration curve shown in Figure 15 has been disclosed and obviously the departing from of above-mentioned ideal state.Comprise that chemical tracer reaction carries the storage layer simulation of model to show, the cross-flow of three independent geology interlayers through wellhole is main causes of viewed effect.Early stage operation what stop unconspicuous this cross-flow among the PLT is to inject the dynamically result of pressurization of each layer of stage at tracer agent: the low more scope with layer of total compressibility is more little, then fast more in its mean pressure increase of injection stage.This average pressure reduction that possibly cause passing layer passes through the wellhole cross-flow and rapid balance at rest period.For the particular case of the three layer model of top discussion, cross-flow need reach the outer about 10m of the thick layer of the coupling shown in Figure 15: 6.5m
3The thick outer 4m of layer of amount and 5.0m
3Amount, both all get into the thick layer (with reference to Figure 13) of top 13.5m.Residual oil saturation in the layer of 13.5m is 34% and in other is two-layer, is 20%, and the digital match of resulting optimum is corresponding to volume averaging value 28%, and this is consistent with the expection of storing to this layer.
After this initial " baseline " SWCT, Xiang Jingzhong injects 420m
3Predetermined ASP preparaton carries out 60m subsequently
3Taper polymer flooding and 420m
3Water drive.Subsequently, in identical well, implement SWCT for the second time, measuring residual oil saturation, and estimate the efficient of ASP preparaton thus.According to thinking that this experiment obtains 1% residual oil saturation (uncertain region is 0-6%).This saturated core displacement of reservoir oil result with experiment that separates almost completely meets fully, shows that storage layer condition obtained duplicating in the laboratory suitably.
To in three different oil fields altogether five wells implement similar program, promptly at first be baseline SWCT, inject the stage and then be another time SWCT for ASP then.Preceding two high-quality sandstone storage layers that are positioned at relative heavy oil in these wells; Two well locations are in two Different Strata of middle innage quality sandstone storage layer in addition; The 5th well location is in the carbonate storage layer of densification.In preceding two wells that the same formation and the phase mutual edge distance in identical oil field has only 430m, second well receives less ASP slug (44m in target
3), follow by polymer flooding (131m
3), short taper polymer flooding (20m
3) and last long water drive (830m
3).Though the baseline SWCT of this second well causes and the similar residual oil saturation of first well (25%), according to thinking that final SWCT obtains 23% oily saturation degree.Although the ASP slug obviously shortens, from experiment core displacement of reservoir oil result, separating of this obvious deficiency is saturated still very unexpected.But before more deep analysis; The unevenness and the unsettled fluid displacement that can not compellently be local storage layer cause water base chemical tracer slug infiltration through full-bodied ASP slug and polymer flooding, thereby in fact SWCT produces once more and obviously surpasses ASP and handle the original residual oil saturation that can reach.Generation dilution alkali and polymkeric substance have been supported this hypothesis when the chemical tracer slug write down between payback period.Therefore, can judge that this SWCT technology is not suitable for the efficient of confirming that small-sized (industrial scale) EOR handles, this experience merits attention concerning experimental design subsequently.Still need the latter is carried out interpretation of result.
The pattern oil displacement experiment
Though the single well chemical tracer experimentalists and technicians provide selected ASP preparaton for the underground evidence of separating saturated validity, it can not confirm the durability of said ASP method in the typical displacement of reservoir oil is used through design: chemicals is in underground stability duration of the whole pattern displacement of reservoir oil; The formation of oil band and stable displacement thereof; Be subject to the influence of storage layer unevenness; Split the maximum sustainable injection flow of ASP slug and polymer flooding under the condition at no uncontrollable storage lamination; The optimum industrial volume of these slugs.Except these with underground relevant uncertainty, still have very big challenge for the design of ground ASP injecting scheme: near withdrawal well with in the formation of production equipment place carbonate scale or silicon dioxide dirt; The exploitation of oil emulsion under low-down oil water interfacial tension; The supply chain of related chemicals and processing.
The main standard of this work is: maximize data is obtained like the oil suction, is separated saturated and the factor of gathering; Tolerance to well or equipment failure; The quantification that emulsification and dirt form and alleviating; Representational geology setting; The feasible lab scale duration.The risk of having confirmed comprises that producing well is neighbouring by ASP Pollution by Chemicals and uncontrollable pressure break.
Based on the above, the length of side is that five dot patterns that reverse (center is injected well and surrounded by four summit producing wells) of 75m * 75m are considered to best half measure.In addition, if desired, this pattern allows through the summit producing well being converted into the injection well and drilling out four new summit producing wells and lab scale is expanded to bigger pattern scale in the bigger distance around original lab scale pattern.Use the storage layer analogy model of demarcating through above-mentioned core oil displacement experiment, begin to carry out the ASP prognosis modelling by existing " history-coupling " oil field model of carefully formatting.Injection and production flow results are shown in Figure 16, and the effluent concentration curve of expection is shown among Figure 10.Total duration is 1.5 years, approximately half a year flower ASP inject and polymer flooding on, and be used for the water drive stage subsequently excess time.Generation through the lab scale operation back oil band in 1 year is accomplished basically.Suppose chemicals penetrate occur in 0.3-0.4 after, expect that then a part of oily band will be with the emulsified state extraction, though surfactant concentrations is less relatively.This is owing in single five dot patterns that reverse, have the production diluted stream, and this ASP for the oil field scope implement and be not true to type.
Exemplary:
In one embodiment of the invention, disclose and a kind ofly produced oil and/or the method for gas, having comprised: the suitable storage layer in location in subsurface formations from subsurface formations; Set up the storage layer model; Fill model with laboratory data; Simulation storage layer is to confirm based on the fluid displacement of the fluid that is injected with the fluid that is produced; Confirm to be used to wait to inject the optimum fluid mixture of fluid based on a series of sensitivity analysis of carrying out with model; Probing first well in the stratum; In first well, inject optimum fluid mixture; Probing second well in the stratum; With produce oil and/or gas by second well.In some embodiments, first well is at a distance of 25 meters-1 kilometer in second well.In some embodiments, optimum fluid mixture comprises water, surfactant, polymkeric substance and alkali.In some embodiments, said method also is included in optimum fluid mixture is released into the mechanism of in the stratum, injecting water-based mixture after the stratum.In some embodiments, fill model with laboratory data and also comprise the optimum salinity of confirming surfactant in the optimum fluid mixture.In some embodiments, fill model with laboratory data and also comprise the optimum salinity of confirming through the soap of alkali in the optimum fluid mixture and the reaction of the oil in stratum formation.In some embodiments, drilling first well comprises also that probing comprises the first well array of 5-500 mouth well and wherein drills second well and comprises that also probing comprises the second well array of 5-500 mouth well.In some embodiments, fill model with laboratory data and also comprise the viscosity of confirming optimum fluid mixture based on the volume that adds the polymkeric substance in the potpourri to.In some embodiments, said method is mixed optimum fluid mixture before also being included in and injecting potpourri.In some embodiments, before injecting optimum fluid mixture, said subsurface formations comprises the oil that viscosity is the 0.5-250 centipoise.In some embodiments, the ASP potpourri curve and second well that first well is included in the stratum are included in the oil recovery curve in the stratum, and said method also comprises overlapping between ASP potpourri curve and the oil recovery curve.In some embodiments, fill model with laboratory data and also comprise the core article enforcement core oil displacement experiment of using from the stratum that comprises formation oil.In some embodiments, implement a series of sensitivity analysis with model and comprise the optimal value that changes every kind of also definite said every kind of component of component in the potpourri.In some embodiments, the oil in the stratum has first viscosity and optimum fluid mixture has second viscosity, and first viscosity is in 75 centipoises of second viscosity.In some embodiments, the oil in the stratum has first viscosity and optimum fluid mixture has second viscosity, and second viscosity is about 25-200% of first viscosity.In some embodiments, second well produces optimum fluid mixture and oil and/or gas.In some embodiments, if said method also comprises from oil and/or gas, reclaiming the optimum fluid mixture that exists and choosing wantonly then the optimum fluid mixture that at least a portion reclaimed is refilled in the stratum.In some embodiments, the injection pressure of optimum fluid mixture is than injecting the high 0-37 of initial storage stressor layer that measures before the beginning, 000kPa.In some embodiments, subsurface formations has the perviousness of 0.0001-15 darcy, for example the perviousness of 0.001-1 darcy.In some embodiments, said method comprises also that oil that at least a portion is gathered and/or cyclostrophic turn to and is selected from following material: transport fuel such as gasoline and diesel oil, heater oil, lubricant, chemicals and/or polymkeric substance.
Those skilled in the art will be understood that under the situation that does not depart from its essence and scope, to have multiple improvement and variation for disclosed embodiment of the present invention, structure, material and method.Therefore, the scope of hereinafter accompanying claims and functional equivalent thereof are not limited by the disclosed here particular with description should, because they are exemplary in itself.
Claims (20)
1. one kind produces oil and/or the method for gas from subsurface formations, comprising: the suitable storage layer in location in subsurface formations; Set up the storage layer model; Fill model with laboratory data; Simulation storage layer is to confirm based on the fluid displacement of the fluid that is injected with the fluid that is produced; Confirm to be used to wait to inject the optimum fluid mixture of fluid based on a series of sensitivity analysis of carrying out with model; Probing first well in the stratum; In first well, inject optimum fluid mixture; Probing second well in the stratum; With produce oil and/or gas by second well.
2. the process of claim 1 wherein that first well is at a distance of 25 meters-1 kilometer in second well.
3. one of claim 1-2 or multinomial method, wherein optimum fluid mixture comprises water, surfactant, polymkeric substance and alkali.
4. one of claim 1-3 or multinomial method also are included in optimum fluid mixture are released into the mechanism of in the stratum, injecting water-based mixture after the stratum.
5. one of claim 1-4 or multinomial method are wherein filled model with laboratory data and are also comprised the optimum salinity of confirming surfactant in the optimum fluid mixture.
6. one of claim 1-5 or multinomial method are wherein filled model with laboratory data and are also comprised the optimum salinity of confirming through the soap of alkali in the optimum fluid mixture and the reaction of the oil in stratum formation.
7. one of claim 1-6 or multinomial method are wherein drilled first well and are comprised also that probing comprises the first well array of 5-500 mouth well and wherein drills second well and comprise that also probing comprises the second well array of 5-500 mouth well.
8. one of claim 1-7 or multinomial method are wherein filled model with laboratory data and are also comprised the viscosity of confirming optimum fluid mixture based on the volume that adds the polymkeric substance in the potpourri to.
9. one of claim 1-8 or multinomial method also are included in the injection potpourri and mix optimum fluid mixture before.
10. one of claim 1-9 or multinomial method, wherein before injecting optimum fluid mixture, said subsurface formations comprises the oil that viscosity is the 0.5-250 centipoise.
11. one of claim 1-10 or multinomial method, wherein the ASP potpourri curve and second well that are included in the stratum of first well is included in the oil recovery curve in the stratum, and said method also comprises overlapping between ASP potpourri curve and the oil recovery curve.
12. one of claim 1-11 or multinomial method are wherein filled model with laboratory data and are also comprised the core article enforcement core oil displacement experiment of using from the stratum that comprises formation oil.
13. the method for claim 12 is wherein implemented a series of sensitivity analysis with model and is comprised the optimal value that changes every kind of also definite said every kind of component of component in the potpourri.
14. one of claim 1-13 or multinomial method, wherein the oil in the stratum has first viscosity and optimum fluid mixture has second viscosity, and first viscosity is in 75 centipoises of second viscosity.
15. one of claim 1-14 or multinomial method, wherein the oil in the stratum has first viscosity and optimum fluid mixture has second viscosity, and second viscosity is about 25-200% of first viscosity.
16. one of claim 1-15 or multinomial method, wherein second well produces optimum fluid mixture and oil and/or gas.
17. one of claim 1-16 or multinomial method refill the optimum fluid mixture that at least a portion reclaimed in the stratum if also comprise from oil and/or gas, reclaiming the optimum fluid mixture that exists and choosing wantonly then.
18. one of claim 1-17 or multinomial method, wherein the injection pressure of optimum fluid mixture is than injecting the high 0-37 of initial storage stressor layer that measures before the beginning, 000kPa.
19. one of claim 1-18 or multinomial method, wherein subsurface formations has the perviousness of 0.0001-15 darcy, for example the perviousness of 0.001-1 darcy.
20. one of claim 1-19 or multinomial method comprise also that oil that at least a portion is gathered and/or cyclostrophic turn to be selected from following material: transport fuel such as gasoline and diesel oil, heater oil, lubricant, chemicals and/or polymkeric substance.
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| PCT/US2011/021493 WO2011090921A1 (en) | 2010-01-20 | 2011-01-18 | Systems and methods for producing oil and/or gas |
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| US (1) | US20120292025A1 (en) |
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| US11434758B2 (en) * | 2020-05-17 | 2022-09-06 | North Oil Company | Method of assessing an oil recovery process |
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| CA2896311A1 (en) | 2013-01-16 | 2014-07-24 | Shell Internationale Research Maatschappij B.V. | Method, system, and composition for producing oil |
| WO2014151289A1 (en) * | 2013-03-15 | 2014-09-25 | Meadwestvaco Corporation | Method and composition for enhanced oil recovery using phosphorus-tagged surfactants |
| WO2014151284A1 (en) * | 2013-03-15 | 2014-09-25 | Meadwestvaco Corporation | Method and composition for hydraulic fracturing |
| CN103939078A (en) * | 2014-03-27 | 2014-07-23 | 上海井拓石油开发技术有限公司 | Equal-fluidity fuel scavenge and fracturing integrated technology |
| WO2016100103A1 (en) | 2014-12-15 | 2016-06-23 | Shell Oil Company | Process and composition for alkaline surfactant polymer flooding |
| US10641083B2 (en) | 2016-06-02 | 2020-05-05 | Baker Hughes, A Ge Company, Llc | Method of monitoring fluid flow from a reservoir using well treatment agents |
| CN108266182B (en) * | 2016-12-30 | 2021-08-31 | 中国石油天然气股份有限公司 | Method and device for selecting fracture distribution mode of horizontal well staged fracturing |
| US11254861B2 (en) | 2017-07-13 | 2022-02-22 | Baker Hughes Holdings Llc | Delivery system for oil-soluble well treatment agents and methods of using the same |
| US11567058B2 (en) * | 2017-09-22 | 2023-01-31 | Chevron U.S.A. Inc. | Process for optimized chemical enhanced recovery |
| CA3079526C (en) | 2017-11-03 | 2022-06-28 | Baker Hughes, A Ge Company, Llc | Treatment methods using aqueous fluids containing oil-soluble treatment agents |
| CA3095506A1 (en) * | 2018-04-09 | 2019-10-17 | Alchemy Sciences, Inc. | Multi-functional surfactant solution for improving hydrocarbon recovery |
| US10961444B1 (en) | 2019-11-01 | 2021-03-30 | Baker Hughes Oilfield Operations Llc | Method of using coated composites containing delayed release agent in a well treatment operation |
| US20220254455A1 (en) * | 2021-02-11 | 2022-08-11 | Saudi Arabian Oil Company | Utilizing hydraulic simulation to evaluate quality of water in salt water disposal systems |
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| US20060289157A1 (en) * | 2005-04-08 | 2006-12-28 | Rao Dandina N | Gas-assisted gravity drainage (GAGD) process for improved oil recovery |
| US20070267191A1 (en) * | 2006-05-17 | 2007-11-22 | Jochen Pfeiffer | Method of Modifying Permeability between Injection and Production Wells |
| US20090188669A1 (en) * | 2007-10-31 | 2009-07-30 | Steffen Berg | Systems and methods for producing oil and/or gas |
| US20090194276A1 (en) * | 2008-01-31 | 2009-08-06 | Total E&P Usa, Inc. | Determination of an actual optimum salinity and an actual optimum type of microemulsion for surfactant/polymer flooding |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US11434758B2 (en) * | 2020-05-17 | 2022-09-06 | North Oil Company | Method of assessing an oil recovery process |
Also Published As
| Publication number | Publication date |
|---|---|
| US20120292025A1 (en) | 2012-11-22 |
| WO2011090921A1 (en) | 2011-07-28 |
| CN102763118B (en) | 2015-02-11 |
| RU2012135549A (en) | 2014-02-27 |
| CA2784910A1 (en) | 2011-07-28 |
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