CN104024567A - Method of producing oil - Google Patents
Method of producing oil Download PDFInfo
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- CN104024567A CN104024567A CN201280065333.1A CN201280065333A CN104024567A CN 104024567 A CN104024567 A CN 104024567A CN 201280065333 A CN201280065333 A CN 201280065333A CN 104024567 A CN104024567 A CN 104024567A
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- slug
- oil
- solvent
- well
- stratum
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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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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
Abstract
The present disclosure relates to enhanced oil recovery methods including the injection of solvent and polymer floods to increase hydrocarbon production from oil bearing underground rock formations. One method includes injecting a solvent slug into the underground formation for a first time period from a first well. The solvent slug solubilizes the oil and generates a mixture of mobilized oil and solvent. An aqueous polymer slug may then be injected into the underground formation for a second time from the first well. The polymer slug may have a viscosity greater than the solvent slug and thereby generates an interface between the solvent slug and the polymer slug. The solvent slug and the mobilized oil are then forced towards a second well using a buoyant hydrodynamic force generated by the aqueous polymer slug. Oil and/or gas may then be produced from the second well.
Description
Technical field
Present disclosure relates to enhanced oil recovery method, and relate to especially inject solvent and polymer oil-displacing agent (flood) thus combination increase and produce hydrocarbon from oil-containing subsurface rock stratum.
Background technology
Enhanced oil recovery (EOR) is for increasing the oil recovery of worldwide hydrocarbonaceous lithostratigraphy.There is the EOR method of three kinds of main Types: heat, chemical/polymer and gas inject, every kind can be worldwide for increasing the oil recovery from reservoir, and exceeding conventional hydrocarbon, to extract measure in the cards.These methods also can extend the life-span of reservoir or increase the overall oil recovery of reservoir.
In brief, hot EOR is by adding heat to play a role to hydrocarbonaceous reservoir.The hot EOR form of the most extensively implementing is used steam, and this steam can flow freely to adjacent producing well oil for reducing oil viscosity.Chemistry EOR, on the other hand, needs to utilize to be designed for and reduces chemical agent or the solvent of capillary force of holding back Residual oil reservoir is driven and swept, and gathers thereby strengthen hydrocarbon.Polymer EOR utilizes the polymer of the displacement sweep efficiency that improves the water injecting that hydrocarbonaceous reservoir is driven and swept.Gas inject, also referred to as mixed water injection, some is similar to chemical EOR and plays a role.By injecting the fluid miscible with oil, the Residual oil that can more easily gather and hold back.
One of advantage of chemistry EOR is the compatibility of the solvent that uses together with oil phase.In theory, in 1D displacement, utilize chemical EOR can realize 100% the efficiency of gathering.In practice, but, utilize the gather/displacement efficiency of the chemical EOR of solvent to be limited to the unstability of flow fronts, for example viscous fingering and Action of Gravity Field.In the time that low viscosity solvent trends towards " fingering " by larger oily of viscosity in reservoir, there is viscous fingering.Once this fingering arrives producing well, very small amount of stagnant oil is finally replaced.Gravity is to solvent generation effect, and mobile oil causes conventionally for reservoir and the power of overstating exceeds normal range (NR) or underrun.
Summary of the invention
Present disclosure relates to enhanced oil recovery method, thereby and relates to especially the combination increase of injecting solvent and polymer oil-displacing agent from oil-containing subsurface rock stratum production hydrocarbon.
Aspect of present disclosure, the method for producing oil from subsurface formations is disclosed.Described method can comprise from the first well to be injected slug of solvent or be otherwise placed into subsurface formations in very first time section.Slug of solvent can be configured for dissolved oil and produce mobile oily mixture.In one or more embodiments, the density of slug of solvent be oil density be less than 90% or at least 110%.Method can further comprise from the first well to be injected waterborne polymeric slug or be otherwise placed into subsurface formations within the second time.The viscosity of polymer slug can be greater than slug of solvent.In some embodiments, the viscosity of polymer slug can be at least 5 centipoises.Polymer slug can be configured between polymer slug and the oily mixture of movement and produce interface.The waterborne polymeric slug that mobile oil and the mixture of slug of solvent can inject by utilization is driven towards the second well, and can produce oil and/or gas from the second well subsequently.
At present disclosure on the other hand, the other method for producing oil from subsurface formations is disclosed.Described method can comprise from the first well injects subsurface formations by carbon disulfide slug in very first time section, and utilizes carbon disulfide slug dissolved oil, thereby produces mobile oily mixture.Described method also can comprise from the first well injects subsurface formations by waterborne polymeric slug within the second time.It can be that to inject at least 1.5 times of pore volume of slug of solvent large that waterborne polymeric slug injects the pore volume on stratum.In addition, the viscosity of waterborne polymeric slug can be 5 centipoise-50 centipoises.Described method can further be included between carbon disulfide slug and waterborne polymeric slug and produce hydrodynamic force, utilizes hydrodynamic force to promote carbon disulfide slug and passes stratum with mobile oily mixture, and produce oil from the second well being communicated with the first well fluids.
By reading the below description of preferred embodiment, those skilled in the art will easily apparent the features and advantages of the present invention.
Brief description of the drawings
Comprise that the following drawings is for some aspect of the present invention is described, and should not be considered to unique embodiment.Can there is the equivalent in a large amount of amendments, variation, combination and form and function in disclosed theme, as those skilled in the art with benefit from that present disclosure can expect.
Fig. 1 has described according to one or more embodiments for produce the system of hydrocarbon from subsurface reservoir.
Fig. 2 a has described the well pattern system according to one or more embodiments.
Fig. 2 b has described according to the well pattern system of Fig. 2 a during the exemplary enhanced oil recovery method of one or more embodiments.
Fig. 3 has described according to one or more embodiments for produce another system of hydrocarbon from subsurface reservoir.
Fig. 4 has described according to the enlarged drawing of the subsurface formations during the exemplary enhanced oil recovery method of one or more embodiments.
Fig. 4 a is the figure that shows that oil viscosity reduces in the time interacting with multi-solvents and solvent/polymer mixture.
Fig. 5 has described to utilize according to the illustrative methods timeline of the injection of the exemplary enhanced oil recovery method of one or more embodiments and production.
Describe in detail
Present disclosure relates to enhanced oil recovery method, thereby and relates to especially the combination increase of injecting solvent and polymer oil-displacing agent from oil-containing subsurface rock stratum production hydrocarbon.
The invention provides and utilize miscible solvent and immiscible polymer oil displacement agent to extract improving one's methods of hydrocarbon from subsurface reservoir.At least one advantage of described disclosure is the displacement stability of miscible solvent and the oily enhancing of moving.Viscous fingering and Action of Gravity Field (for example gravity exceeds normal range (NR) or gravity underrun reservoir) minimize substantially.As a result, miscible solvent more effectively or otherwise come into force for enhanced oil recovery method.This has not only improved the efficiency of gathering of reservoir, has also effectively utilized solvent and polymer simultaneously.
With reference to figure 1, show for from underground hydrocarbon containing formation, for example oily reservoir is produced the system 100 of hydrocarbon (for example, oil and/or gas).Particularly, system 100 can be configured for from the first subsurface formations 102, the second subsurface formations 104, the three subsurface formations 106, and/or the 4th subsurface formations 108 extracts hydrocarbon.As shown, production facility 110 provides conventionally on ground, and well 112 derives and pass through the first and second stratum 102,104 from ground, finally ends in the 3rd stratum 106.The 3rd stratum 106 can comprise one or more layer segments 114 that are adjacent to, and hydrocarbon or other fluid can be adjacent to remove and be delivered to layer segment 114 production facility 110 from one or more via well 112.Gas and liquid are disconnected from each other at production facility 110 places, and gas storage through extracting is at gas reservoir 116, and simultaneously the fluid storage through extracting is in liquid memory 118.
With reference to figure 2a, show according to the top view of the array 200 of the example well of one or more embodiments.In some embodiments, in array 200, describe can be substantially similar to every mouthful of well described below the completion 112 of describing about Fig. 1 above.As shown, array 200 comprises the first well group 202 (being represented by horizontal crosshatch) and the second well group 204 (being represented by diagonal cross-hatch).In some embodiments, the array 200 of well can comprise approximately 10 mouthfuls of well-Yue 1000 mouthful wells altogether.For example, the array 200 of well can comprise approximately 5 mouthfuls of well-Yue 500 mouthful wells from the first well group 202, and from approximately 5 mouthfuls of well-Yue 500 mouthful wells of the second well group 204.
Can arrange that every mouthful of well in the first well group 202 leaves arbitrary neighborhood well the first lateral separation 230 and the second lateral separation 232 in the first well group 202.The first and second lateral separations 230,232 can be conventionally orthogonal.Similarly, can arrange that every mouthful of well in the second well group 204 leaves arbitrary neighborhood well the first lateral separation 236 and the second lateral separation 238 in the second well group 204, wherein the first and second lateral separations 236,238 can be conventionally orthogonal.In addition, every mouthful of well in the first well group 202 can leave arbitrary neighborhood well the 3rd distance 234 in the second well group 204.As a result, every mouthful of well in the second well group 204 can leave arbitrary neighborhood well the 3rd distance 234 in the first well group 202.
In some embodiments, 4 mouthfuls of individual wells that every mouthful of well in the first well group 202 can be belonged to the second well group 204 around.Similarly, 4 mouthfuls of individual wells that every mouthful of well in the second well group 204 can be belonged to the first well group 202 around.In some embodiments, the first and second lateral separations 230,232 can be approximately 5 meter-Yue 1000 meter, for example, approximately 10 meter-Yue 500 meter, approximately 20 meter-Yue 250 meter, approximately 30 meter-Yue 200 meter, approximately 50 meter-Yue 150 meter, approximately 90 meter-Yue 120 meter, or approximately 100 meters.Similarly, in some embodiments, the first and second lateral separations 236,238 can be approximately 5 meter-Yue 1000 meter, for example, approximately 10 meter-Yue 500 meter, approximately 20 meter-Yue 250 meter, approximately 30 meter-Yue 200 meter, approximately 50 meter-Yue 150 meter, approximately 90 meter-Yue 120 meter, or approximately 100 meters.In addition, the 3rd distance 234 can be approximately 5 meter-Yue 1000 meter, for example, approximately 10 meter-Yue 500 meter, approximately 20 meter-Yue 250 meter, approximately 30 meter-Yue 200 meter, approximately 50 meter-Yue 150 meter, approximately 90 meter-Yue 120 meter, or approximately 100 meters.
The top view of the array 200 of well although describe Fig. 2 a above, wherein the first and second well groups 202, the 204th, vertically arranged well, but Fig. 2 a can be similarly and do not describe the side sectional view of array 200 circumscribed, and do not depart from the scope of present disclosure.For example, Fig. 2 a can alternatively describe the side sectional view of array 200, and wherein the first and second well group 202,204 horizontal arrangement are in stratum.Therefore, no matter should understand the first and second well groups 202,204th, horizontal or vertical layout or its combination, system and method disclosed herein can similarly be brought into play function.As used herein, " vertically " well can refer to the well tilting.In other embodiments, the array 200 of well can represent j-type well or the well of other type arbitrarily well known by persons skilled in the art.
Can complete and utilize the array 200 of well from subsurface formations recovery of oil and/or gas by any known process.Applicable method comprises subsea production, surface production, once, secondary or three times produce, etc.In some embodiments, as above, about as described in Fig. 1, oil and/or gas can be gathered to producing well 112 from stratum 102,104,106,108, and flow through well 112 arrive production facility 110 for processing.In other embodiments, enhanced oil recovery (EOR) technology can be for strengthening from the oil on stratum 102,104,106,108 and/or flowing of gas.As below in greater detail, exemplary EOR technology and method can comprise to be injected solvent flooded agent or is otherwise placed in stratum 102,104,106,108 one or more so that the part viscous oil wherein existing dissolves and is mobile.Injecting after solvent, waterborne polymeric oil displacement agent can be injected stratum with the oil that orders about dissolving towards adjacent producing well, and in the time that solvent passes stratum, improve forward's stability of solvent simultaneously.
In one or more embodiments, solvent can be miscible enhanced oil recovery reagent, and it conventionally and high-viscosity oil is miscible and can make oil dissolving and movement to gather sooner and more effectively.Miscible enhanced oil recovery reagent can include, but not limited to carbon disulfide preparaton.Carbon disulfide preparaton can comprise carbon disulfide and/or carbon disulfide derivatives, for example thiocarbonate, xanthates, their mixture, and similar item.In other embodiments, carbon disulfide preparaton can further comprise following one or more: hydrogen sulfide, sulphur, carbon dioxide, hydrocarbon, and their mixture.Other miscible enhanced oil recovery reagent being applicable to will have the density that is less than about 0.7g/ml, and can include but not limited to: hydrogen sulfide, carbon dioxide, octane, pentane, LPG, C
2-C
6aliphatic hydrocarbon, nitrogen, diesel oil, petroleum solvent, diluent naphtha, asphalt solution, kerosene, acetone, dimethylbenzene, trichloroethanes, aforesaid two or more mixture, or other miscible enhanced oil recovery reagent as known in the art.In some embodiments, applicable solvent or miscible enhanced oil recovery reagent and oil in subsurface formations are to contact first miscible or multiple-contact is miscible.
In one or more embodiments, waterborne polymeric oil displacement agent can be characterized by and be designed for the unmixing enhanced oil recovery reagent that helps the oil of solvent flooded agent and dissolving to move through stratum.Unmixing enhanced oil recovery reagent can be designed for the mobility of water in the hole that reduces stratum in addition, and as understood, this can allow solvent flooded agent more easily to move through stratum.Unmixing enhanced oil recovery reagent comprises polymer and can comprise other unmixing enhanced oil recovery reagent, such as but not limited to: monomer, surfactant, the water of gas or liquid form, carbon dioxide, nitrogen, air, aforementioned two or more mixture, or other unmixing enhanced oil recovery reagent as known in the art.Applicable polymer can include but not limited to: polyacrylamide, the polyacrylamide of partial hydrolysis, polyacrylate, ethylenic copolymer, biopolymer, carboxymethyl cellulose, polyvinyl alcohol, PSS, PVP, AMPS (2-acrylamide-2-methyl propane sulfonic acid ester), their combination, or similar item.The example of ethylenic copolymer comprises the copolymer of acrylic acid and acrylamide, the copolymer of acrylic acid and lauryl acrylate, the copolymer of lauryl acrylate and acrylamide.The example of biopolymer comprises xanthans and guar gum.In some embodiments, polymer can be cross-linked in formation crude position.In other embodiments, polymer can produce in formation crude position.In other embodiments, applicable polymer comprises liquid tackifiers, for example ShellVis50.In addition, in some embodiments, applicable unmixing enhanced oil recovery reagent and the oil in stratum are not to contact first miscible or multiple-contact is miscible.
With reference now to Fig. 2 b,, show according to disclosed one or more embodiments, utilize the array 200 of the well of one or more exemplary EOR technical finesses.In some embodiments, solvent and/or polymer oil-displacing agent are injected to the second well group 204 and produce injection profile 208.The larger oil of viscosity that the solvent injecting is held back low layer dissolves and is mobile, it can be gathered via the first well group 202, as gained oil recovery section 206 is described.In some embodiments, the oil that the polymer oil-displacing agent of injection can order about solvent and dissolving/movement towards the first well group 202 for the production of.In an alternative embodiment, each slug of solvent and polymer oil-displacing agent is injected to the first well group 202 in the stage replacing, and subsequently from the second well group 204 recovery of oil.
In some embodiments, can in very first time section, solvent flooded agent be injected to the first well group 202 continuously, after very first time section, can within the second time period, produce oil and/or gas from the second well group 204.In other embodiments, after very first time section, can waterborne polymeric oil displacement agent be injected to the first well group 202 within the second time period.Can during very first time section or during the second time period or simultaneously during the first and second time periods or comprising very first time section and the certain hour section after the second time period and can comprise in the 3rd time period of the certain hour section in the first and/or second time period, produce oil and/or gas from the second well group 204.But, should understand, injection and manufacturing process can be undertaken by the first or second well group 202,204, and do not depart from the scope of present disclosure.
The first, the second, and the 3rd time period can be the time of predetermined length, it can be characterized by the complete cycle together.In some embodiments, exemplary cycle can be crossed over approximately 12 hours-Yue 1 year.In other embodiments, but exemplary cycle can be crossed over approximately 3 days-Yue June, or approximately 5 days-Yue March.In one or more embodiments, the cycle of each order can be than rise time in cycle before.For example, the cycle of each order can be about 5%-approximately 10% than the cycle before.In at least one embodiment, the cycle of order can be about 8% than the cycle before.
In some embodiments, can carry out multiple cycles, its be included in inject or place solvent and polymer oil-displacing agent and from stratum produce oil and/or gas between well group 202,204 alternately.For example, in very first time section, a well group can inject with another well group and can produce, and within the second time period, they can be changed subsequently.
In some embodiments, can in the time that the cycle starts, inject solvent flooded agent, and can be in the time of end cycle injection of polymer oil displacement agent or comprise the mixture of one or more unmixing enhanced oil recovery reagent.In one or more embodiments, the beginning in cycle can be the first 10%-approximately 80% in cycle, the first 20%-approximately 60% in cycle, or the first 25%-approximately 40% in cycle.The remainder in cycle can be only crossed in the end in cycle.
In some embodiments, injecting any enhanced oil recovery reagent (, solvent and/or polymer) oil viscosity that exists in stratum before can be that (MPa is s) at least about 100 centipoises, or (MPa s) at least about 500 centipoises, or at least about 1000 centipoises (MPa s), or at least about 2000 centipoises (MPa s), or (MPa s) at least about 5000 centipoises, or (MPa s) at least about 10,000 centipoises.In other embodiments, but, can be at the most approximately 5 injecting stratum exists before any enhanced oil recovery reagent oil viscosity, 000,000 centipoise (MPa s), or at the most approximately 2,000, (MPa s) for 000 centipoise, or at the most approximately 1,000, (MPa is s) for 000 centipoise, or at the most approximately 500,000 centipoises (MPa s).
Solvent flooded agent is injected or is placed to stratum 106 (Fig. 1) and can complete by method known to those skilled in the art.In at least one embodiment, solvent flooded agent is injected to the single catheter of single well (well 112 of for example Fig. 1).Allowing subsequently for example carbon disulfide preparaton of solvent to be soaked into adjacent hydrocarbon containing formation neutralization reacts with viscous oil.Along with carbon disulfide reacts with oil, oil dissolves and starts mobile.After solvent has soaked the time of scheduled volume, solvent can pump out stratum 106 or utilize waterborne polymeric oil displacement agent to drive to sweep through stratum 106 by well 112 subsequently with mobile oily mixture and arrive adjacent producing well.
In one or more embodiments, the density of solvent can be oil density be less than 90% or oil density at least 110%.Add other reagent or surfactant to described solvent and can help to realize higher or lower density.For example can be by CO
2, H
2s, C
3, C
4, and/or C
5one or more in hydrocarbon add in described solvent to help to realize the suitable density ratio between solvent and oil.
With reference now to Fig. 3,, shown for from underground hydrocarbon containing formation another system 300 that for example oily reservoir is produced hydrocarbon (, oil and/or gas).System 300 can be similar to the system 100 of describing about Fig. 1 in some aspects above.Therefore, can be with reference to figure 1 understanding system 300 best, wherein similarly numeral is for parts like representation class, and these similar parts will be not described in detail.In one or more embodiments, production facility 110 can further comprise that production oil storage tank 302 and system 300 can further comprise the second well 304.Be similar to the first well 112, by one or more be adjacent to layer segment 306 around the second well 304 extend through the first and second stratum 102,104 and finally end in the 3rd stratum 106.Should be understood that every mouthful of well 112,302 be adjacent to separately layer segment 114 and 306 can optionally rupture and/or bore a hole with promote produce.
Produce oil storage tank 302 and can be configured for and store miscible and/or unmixing enhanced oil recovery reagent and/or preparaton (, solvent and/or polymer) for injecting subsurface formations 102,104, in 106,108.In one or more embodiments, production oil storage tank 302 is coupled to joinably the second well 304 and is designed for provides solvent and/or waterborne polymeric for injecting wherein.In other embodiments, but production oil storage tank 302 can be coupled to joinably the first well 112 and be designed for provides solvent and/or waterborne polymeric for injecting wherein.In other embodiments, production oil storage tank 302 can be coupled to joinably the first and second wells 112,302 simultaneously and be designed for provides solvent and/or waterborne polymeric for injecting simultaneously wherein, and does not depart from the scope of present disclosure.
In some embodiments, the second well 304 can represent to belong to the well of the first well group 202, and the first well 112 can represent to belong to the well of the second well group 204, as above about as described in Fig. 2 a and 2b.In other embodiments, but the second well 304 can represent to belong to the well of the second well group 204, and the first well 112 can represent to belong to the well of the first well group 202.In one or more embodiments, solvent preparaton can be in the second well 304 pumping downwards and inject the 3rd subsurface formations 106 as slug be adjacent to layer segment 306.Once contact with the viscous oil existing in stratum 106, solvent flooded agent dissolved oil and form solvent and oily mixture, described solvent and oily mixture with dissolve previous oil phase than the viscosity that shows reduction.As the result of dissolving, cementitious mixtures still less becomes mobile, thereby more easily from stratum 106, extracts.
In some embodiments, can make mixture flow pass the 3rd subsurface formations 106 via the second well 304 uninterrupted pumping solvents, as shown by arrows, and finally arrive the first well 112 with output to production facility 110.In other embodiments, but solvent flooded agent can be followed the waterborne polymeric oil displacement agent that is adjacent to layer segment 306 that is also injected into the 3rd subsurface formations 106 via the second well 304.In the time of each penetrating ground 106 of solvent flooded agent and solvent and oily mixture, polymer oil-displacing agent can be configured for the displacement stability of improving solvent flooded agent and solvent and oily mixture.
With reference to figure 4, continue with reference to figure 3 simultaneously, show according to one or more embodiments and passed through one or more solvents of the 3rd subsurface formations 106 and the enlarged drawing of polymer slug.As shown, subsurface formations 106 can be defined in top edge 402a and lower limb 402b geographically, thus geographically with second and the 4th subsurface formations 104,108 cut apart or by second and the 4th subsurface formations 104,108 sealing.Although do not show, be to be understood that the first and second wells 112 and 304 can be arranged on any end of subsurface formations 106, enter or leave stratum 106 to inject or to produce fluid.Flow and can press the direction shown in arrow through stratum 106.In other embodiments, but, flow and can reverse, and do not depart from the scope of present disclosure.
Stratum 106 can be by providing the oily oil-bearing layer 404 from light oil-heavy oil scope to form.As shown, slug of solvent 406 can inject stratum 106, once with contact with oil-bearing layer 404, the part 408 that a part 408 that can dissolved oil makes to dissolve more easily moves through stratum 106 and extracts.In some embodiments, can, taking the fracture pressure lower than stratum 106, for example, as the approximately 40%-approximately 90% of fracture pressure, slug of solvent 406 be pumped in stratum 106.
After slug of solvent 406, waterborne polymeric slug 410 can be injected to stratum 106.In one or more embodiments, the polymer using can show the viscosity higher than solvent and with slug of solvent 406 unmixings, and can show with the viscosity of solvent and oily mixture same order and with solvent and oily mixture 408 unmixings.For example, in one or more embodiments, the viscosity of waterborne polymeric slug 410 can be approximately 1 centipoise (MPa s)-Yue 1000 centipoise (MPa s), or 5 centipoises ((MPa s) for MPa s)-100 centipoises.As a result, produce interface 412 by the interfacial tension between slug of solvent 406 and polymer slug 410 and/or capillary pressure.Can utilize CT scan technology, be derived from along the pressure measxurement of multiple pressure taps of the span of landing surface 106 and/or the sampling fluids in the time producing fluid, observe or otherwise measure the interface 412 producing.In operation, interface 412 can provide uniform shell of compression, and its oily mixture 408 that orders about slug of solvent 406 and solvent and dissolving is through the 3rd subsurface formations 106.Therefore, the oily mixture 408 of hydrodynamic force promotion slug of solvent 406 and solvent and dissolving passes stratum 106 with basic forward uniformly.Hydrodynamic force can be initiatively and/or the oily mixture 408 that promotes passively slug of solvent 406 and solvent and dissolving through stratum 106, this depends on whether polymer slug is driven on one's own initiative (for example, by using pump or other driving mechanism) or is driven by the pressure adding up in well and/or stratum 106 passively.
As will be appreciated, this can prove to strengthen slug of solvent 406 in oil-bearing layer 404 replaces the advantage of stability, makes slug of solvent 406 by the forward and/or the oil-bearing layer 404 place's viscous fingerings that not too tend at the oily mixture 408 of solvent and dissolving.For example, the viscosity of multi-solvents (for example carbon disulfide) is less than the oil running in subsurface formations.Similarly, these solvents trend towards naturally in the fingering of flow fronts place.But, as described herein, in the time being followed by polymer slug 410, basic pressure uniformly puts on 412 places, interface, this oily mixture 408 that orders about slug of solvent 406 and solvent and dissolving passes stratum 106 with more uniform process, and the Potential feasibility of viscous fingering is reduced greatly.
Polymer slug 410 also can help to alleviate other forward's flow instability, and for example wherein slug of solvent 406 may tend to the Action of Gravity Field that gravity exceeds normal range (NR) or gravity underrun.For example, for example, along with finer and close solvent (, carbon disulfide) mixes with viscous oil, it is finer and close than remaining oil in stratum 106 that solvent/oil mixture becomes, and gravity orders about solvent/oil mixture 408 and arrive the bottom on stratum 106 naturally.Similarly, along with not too fine and close solvent mixes with viscous oil, the solvent/oil mixture of gained becomes and will order about these solvent/oil mixtures 408 and arrive the top on stratum 106 not as remaining oily densification and natural buoyancy in stratum 106.Result, solvent can order about unevenly by stratum 106, thereby cause gravity to exceed normal range (NR) and gravity underrun, wherein excessive not too fine and close solvent can be on the top on stratum 106 through passing in the bottom on stratum 106 with excessive finer and close solvent, and mid portion does not have throughput simultaneously.But polymer slug 410 strengthens oily displacement and promotion is moved more equably on the whole forward of solvent/oil mixture 408.
In some embodiments, slug of solvent 406 before being injected in stratum 106, can heat to reduce stratum 106 in the viscosity of fluid (such as heavy oil, alkane, asphalitine etc.).In other embodiments, slug of solvent 406 heats and/or boils can be in stratum 106 time, to heat and/or vaporized solvent preparaton.Slug of solvent 406 can heat on one's own initiative or passively.For example slug of solvent 406 can utilize fluid (, steam) or the heater after for example heating to heat.In other embodiments, but slug of solvent 406 can carry out nature heating via the heat of the Lock-in of distributing from stratum 106.In one or more embodiments, salt solution oil displacement agent or catch up with agent (chase) 414 and can inject stratum 106 after polymer slug 410.Salt solution catches up with agent 414 can be configured for the fluid of replacing remaining movement.In at least some embodiments, catch up with agent 414 and utilize nitrogen to carry out.
In other embodiments, can before slug of solvent 406, polymer slug 410 be injected to stratum 106, with pretreatment stratum 106.In addition, the salt solution substituting after polymer slug 410 catches up with agent 414, can inject another slug of solvent 406, is another polymer slug 410 afterwards, thereby produces order alternately.In other embodiments, the pore volume of polymer slug 410 can be at least 1.5 times of slug of solvent 406 pore volumes that inject stratum 106." pore volume " is defined as the pore volume with respect to the stratum 106 of the cumulative volume on stratum." pore volume " also can pointed injection well and producing well between involve (swept) volume, and can easily determine by method known to those skilled in the art.The method comprises Modeling Research.But pore volume also can be by making the highrank fuel salinity water that wherein contains tracer determine from injector well to producing well by stratum.Swept volume is by the volume that average displacement fluid involves on all streams between injector well and producing well.As known to those skilled in the art, this can be by reference to the first moment (the first temporal moment) tracer distribution and determining in the highrank fuel salinity water producing.
With reference to figure 4a, show Figure 41 6, show the reduction of reservoir place oil viscosity in the time that oil contacts with solvent or solvent/polymer combinations.Merit attention, Figure 41 6 has shown as oil and carbon disulfide (CS
2) itself when contact in, as oil and CS
2while contact with the mixture of polystyrene (PS) and as oil and CS
2while contact with the mixture of ShellVis50, oil viscosity reduces.Following table 1 provides CS
2the character of/PS solution at approximately 23 DEG C, and following table 2 provides CS
2the character of/ShellVis50 solution at approximately 23 DEG C.
Table 1
| Concentration, wt% | Density p (g/cm 3) | Viscosity, mu (cP) |
| 0 | 1.26 | 0.4±0.1 |
| 6.9 | 1.26 | 1.0±0.1 |
| 13.2 | 1.25 | 4.3±0.4 |
| 16.2 | 1.24 | 7.4±0.7 |
| 22.4 | 1.22 | 26.8±2.7 |
Table 2
| Concentration, wt% | Density p (g/cm 3) | Viscosity, mu (cP) |
| 0 | 1.26 | 0.4±0.1 |
| 3.4 | 1.26 | 5.1±0.5 |
| 5.5 | 1.25 | 14.9±1.5 |
| 8.3 | 1.24 | 65.9±1.6 |
With reference now to Fig. 5,, continue with reference to figure 3 and 4 simultaneously, show according to the illustrative methods of the injection of disclosed one or more embodiments and production or pattern (pattern) 500.Exemplary patterns 500 can provide for the exemplary injection of the first well group 202 and the explanation of production time (as shown in the timeline of top), and for exemplary injection and the explanation of production time (as shown in the timeline of bottom) of the second well group 204.As shown, inject slug of solvent and shown by checkerboard pattern, injection of polymer slug is by diagonal angle pattern displaying, and white portion demonstration produces oil and/or gas from stratum.
In some embodiments, at times 520 place, interior slug of solvent is injected to the first well group 202 in the time period 502, within the time period 503, produce oil and/or gas from the second well group 204 simultaneously.Can interior slug of solvent be injected to the second well group 204 in the time period 505 subsequently, within the time period 504, produce oil and/or gas from the first well group 202 simultaneously.The cycle that this injection/production cycle of well group 202 and 204 can continue arbitrary number, for example approximately 5-Yue 25 cycles of cycle.
In some embodiments, at times 530 place, owing to having produced oil and/or gas during the time 520, in stratum, may there is cavity.During the time 530, only the forward position of cavity can be filled with slug of solvent, and this slug of solvent utilizes polymer slug to promote to pass through stratum subsequently.For example, can interior slug of solvent be injected to the first well group 202 in the time period 506, can interior polymer slug be injected to the first well group 202 in the time period 508 subsequently, within the time period 507, produce oil and/or gas from the second well group 204 simultaneously.In one or more embodiments, can interior slug of solvent be injected to the second well group 204 in the time period 509 subsequently, can interior polymer slug be injected to the second well group 204 in the time period 511 subsequently, can within the time period 510, produce oil and/or gas from the first well group 202 simultaneously.The cycle that this injection/production cycle of well group 202 and 204 can continue arbitrary number, for example approximately 5-Yue 25 cycles of cycle.
In some embodiments, at times 540 place, between the first well group 202 and the second well group 204, may there is significant hydraulic communication.In one or more embodiments, can interior slug of solvent be injected to the first well group 202 in the time period 512, can interior polymer slug be injected to the first well group 202 in the time period 514 subsequently, can within the time period 515, produce oil and/or gas from the second well group 204 simultaneously.Solvent and polymer slug are injected to the first well group 202, produce oil and/or the circulation of gas can continue as required from the second well group 204, for example, as long as produce oil and/or gas from the second well group 204 simultaneously.
In some embodiments, the time period 502,503,504, and/or 505 can be approximately 6 hours-Yue 10 days, and for example, approximately 12 hours-Yue 72 hours, or approximately 24 hours-Yue 48 hours.In some embodiments, each time period 502,503,504, and/or 505 can be from the time 520 until the time 530 increase length.In other embodiments, but, each time period 502,503,504, and/or 505 can be from the time 520 until the time 530 continued relatively invariably for 5-Yue 25 cycles of cycle, for example approximately 10-Yue 15 cycles of cycle.
In some embodiments, the time period 506 is approximately 10%-approximately 50% of the pattern length of time period 506 and time period 508, for example about 20%-approximately 40%, or about 25%-approximately 33%.In some embodiments, the time period 509 is approximately 10%-approximately 50% of the pattern length of time period 509 and time period 511, for example about 20%-approximately 40%, or about 25%-approximately 33%.In some embodiments, the pattern length of time period 506 and time period 508 is approximately 2 days-Yue 21 days, for example approximately 3 days-Yue 14 days, or approximately 5 days-Yue 10 days.In some embodiments, the pattern length of time period 509 and time period 511 is approximately 2 days-Yue 21 days, for example approximately 3 days-Yue 14 days, or approximately 5 days-Yue 10 days.In some embodiments, the pattern length of time period 512 and time period 514 is approximately 2 days-Yue 21 days, for example approximately 3 days-Yue 14 days, or approximately 5 days-Yue 10 days.
Refer again to Fig. 3, make oil and solvent and polymer after separating, can get back to production reservoir vessel 302 for circulation and placement with post processing solvent preparaton.Process solvent preparaton can comprise for circulation boil, condensation, filtration and/or and solvent reaction.In addition, oil and/or gas can be delivered to refinery and/or treatment facility.Can process oil and/or gas to prepare commercial product, for example transport fuel, for example gasoline and diesel oil, domestic fuel oil, sliding agent, chemicals, and/or polymer.Processing can comprise that distillation and/or distillate oil and/or gas are to produce one or more distillate cuts.In some embodiments, can make oil and/or gas, and/or one or more distillate cut experiences one or more processes below: catalytic cracking, hydrocracking, hydrotreatment, coking, thermal cracking, distillation, reforms, polymerization, isomerization, alkylation, blend, and dewaxing.
Therefore, the present invention is very suitable for obtaining mentioned target and advantage and intrinsic those targets and advantage wherein.Above-disclosed particular is only for example because can with benefit from instruction of the present invention those skilled in the art apparent difference but form amendment of equal value and put into practice the present invention.In addition,, except what describe in claims, do not intend to be limited to the details of the construction or design showing herein.Therefore it is evident that, above-disclosed particular exemplary embodiment can change, combines or revise, and within all these variants are considered to be in scope and spirit of the present invention.Can do not exist herein with no specific disclosure of any element and/or the condition of any optional elements disclosed herein under, compatibly implement exemplary disclosed the present invention herein.Although composition and method are described as " comprising ", " comprising " or " having " various ingredients or step, described composition and method also can " be made up of described various ingredients or step " substantially, or " being made up of described various ingredients or step ".Above-disclosed numerical value and scope can change with a certain amount of.No matter when disclose the number range with upper and lower bound, any numerical value and any included scope that drop within the scope of this are all specifically disclosed.Especially, each number range disclosed herein (following form: " the about b of about a-" or " about a-b " or " from about a to b " of equal value of equal value) should be understood included each numerical value and the scope in wider number range that provided.In addition, the term in claim has its common, conventional implication, unless owner of a patent otherwise defines clearly and clearly.In addition the implication that the indefinite article " a " using in claim, or " " define is in this article one or is greater than an element of introducing.If the use of vocabulary or term exists any conflict with being incorporated to by reference one or more patents or other document herein in this manual, should adopt the definition consistent with this manual.
Claims (14)
1. the method for producing oil from underground petroleum-containing formation, comprising:
Slug of solvent is placed into underground petroleum-containing formation in very first time section from the first well, described slug of solvent is designed for by contacting with oil and oil is dissolved and produce mobile oily mixture, and what wherein the density of slug of solvent was oil density is less than 90% or at least 110%;
Waterborne polymeric slug is placed into subsurface formations within the second time from the first well, the viscosity of polymer slug is greater than mobile oily mixture and is at least 5 centipoises;
Use polymer slug is towards the mobile oil of the second well displacement and the mixture of slug of solvent; With
Produce oil and/or gas from the second well.
2. the process of claim 1 wherein and produce interface between polymer slug and the oil moving and the mixture of solvent.
3. the method for claim 1 or claim 2, wherein slug of solvent comprises carbon disulfide preparaton.
4. the method for claim 1 or claim 2-3 any one, is also included in and salt solution is caught up with to agent after waterborne polymeric slug and be placed in stratum.
5. the method for claim 1 or claim 2-4 any one, also comprises with alternating sequence and repeats to place slug of solvent and waterborne polymeric slug.
6. the method for claim 1 or claim 2-5 any one, the wherein freely polymer of the group of following composition of the polymer of waterborne polymeric slug choosing: polyacrylamide, the polyacrylamide of partial hydrolysis, polyacrylate, ethylenic copolymer, biopolymer, carboxymethyl cellulose, polyvinyl alcohol, PSS, PVP, AMPS (2-acrylamide-2-methyl propane sulfonic acid ester), the copolymer of acrylic acid and acrylamide, the copolymer of acrylic acid and lauryl acrylate, the copolymer of lauryl acrylate and acrylamide, xanthans, and guar gum.
7. the method for claim 1 or claim 2-6 any one, the pore volume of the waterborne polymeric slug of wherein placing in stratum is at least 1.5 times of pore volume of the slug of solvent placed in the stratum before just placing waterborne polymeric slug.
8. the method for claim 1 or claim 2-7 any one, wherein the viscosity of polymer slug is greater than slug of solvent.
9. the method for producing oil from underground petroleum-containing formation, comprising:
First carbon disulfide slug is placed into subsurface formations in very first time section from the first well;
At least a portion oil is contacted with first carbon disulfide slug, thereby produce mobile oil and the mixture of carbon disulfide;
Waterborne polymeric slug is placed into subsurface formations within the second time from the first well, the pore volume of a certain amount of waterborne polymeric slug of wherein placing in stratum is at least 1.5 times of pore volume of first carbon disulfide slug of placing in stratum, and the viscosity of waterborne polymeric slug is that ((MPa s) for MPa s)-100 centipoises for 5 centipoises;
Between first carbon disulfide slug and waterborne polymeric slug, produce hydrodynamic force;
The mixture that utilizes hydrodynamic force to promote first carbon disulfide slug and the oil moving and carbon disulfide passes stratum; With
Produce oil from the second well being communicated with the first well fluids.
10. the method for claim 9, also comprises from the first well and within the 3rd time period, second carbon disulfide slug being placed into subsurface formations.
The method of 11. claims 9 or claim 10, is also included in and salt solution is caught up with to agent after waterborne polymeric slug and be placed in stratum.
The method of 12. claims 9 or claim 10-11 any one, also comprises with alternating sequence and repeats to place first carbon disulfide slug and waterborne polymeric slug.
The method of 13. claims 9 or claim 10-12 any one, wherein said subsurface formations is in and on top edge and lower limb, seals two of described subsurface formations and be adjacent between sub-surface.
The method of 14. claims 9 or claim 10-13 any one, wherein the density of first carbon disulfide slug is at least 110% of oil density.
Applications Claiming Priority (3)
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| US201161581670P | 2011-12-30 | 2011-12-30 | |
| JP61/581,670 | 2011-12-30 | ||
| PCT/US2012/070669 WO2013101599A1 (en) | 2011-12-30 | 2012-12-19 | Method of producing oil |
Publications (1)
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|---|---|
| CN104024567A true CN104024567A (en) | 2014-09-03 |
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Country Status (5)
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| US (1) | US20130168089A1 (en) |
| CN (1) | CN104024567A (en) |
| CA (1) | CA2861858A1 (en) |
| RU (1) | RU2014131481A (en) |
| WO (1) | WO2013101599A1 (en) |
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| CN104974736A (en) * | 2015-06-17 | 2015-10-14 | 成都高普石油工程技术有限公司 | Thickening water drive required for tertiary oil recovery |
| CN106447093B (en) * | 2016-09-12 | 2019-03-19 | 中国海洋石油集团有限公司 | A kind of measuring method of the poly- displacing oil-field greasy filth quantum of output in sea |
| EA038232B1 (en) * | 2016-12-20 | 2021-07-28 | Бп Эксплорейшн Оперейтинг Компани Лимитед | Oil recovery method |
| CN108533239B (en) * | 2018-05-20 | 2019-01-11 | 东北石油大学 | Utilize viscous fingering method and device in gravitational effect control surfactant flooding |
| US10711176B2 (en) * | 2018-10-03 | 2020-07-14 | David O. Trahan | Method, process, apparatus and chemicals to produce and inject paraffin treating compounds |
| US11421663B1 (en) | 2021-04-02 | 2022-08-23 | Ice Thermal Harvesting, Llc | Systems and methods for generation of electrical power in an organic Rankine cycle operation |
| US11644015B2 (en) | 2021-04-02 | 2023-05-09 | Ice Thermal Harvesting, Llc | Systems and methods for generation of electrical power at a drilling rig |
| US11592009B2 (en) | 2021-04-02 | 2023-02-28 | Ice Thermal Harvesting, Llc | Systems and methods for generation of electrical power at a drilling rig |
| US20220316452A1 (en) | 2021-04-02 | 2022-10-06 | Ice Thermal Harvesting, Llc | Systems for generating geothermal power in an organic rankine cycle operation during hydrocarbon production based on working fluid temperature |
| US11493029B2 (en) | 2021-04-02 | 2022-11-08 | Ice Thermal Harvesting, Llc | Systems and methods for generation of electrical power at a drilling rig |
| US11486370B2 (en) | 2021-04-02 | 2022-11-01 | Ice Thermal Harvesting, Llc | Modular mobile heat generation unit for generation of geothermal power in organic Rankine cycle operations |
| US11293414B1 (en) | 2021-04-02 | 2022-04-05 | Ice Thermal Harvesting, Llc | Systems and methods for generation of electrical power in an organic rankine cycle operation |
| US11480074B1 (en) | 2021-04-02 | 2022-10-25 | Ice Thermal Harvesting, Llc | Systems and methods utilizing gas temperature as a power source |
| US11326550B1 (en) | 2021-04-02 | 2022-05-10 | Ice Thermal Harvesting, Llc | Systems and methods utilizing gas temperature as a power source |
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- 2012-12-19 RU RU2014131481A patent/RU2014131481A/en not_active Application Discontinuation
- 2012-12-19 WO PCT/US2012/070669 patent/WO2013101599A1/en active Application Filing
- 2012-12-19 CN CN201280065333.1A patent/CN104024567A/en active Pending
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Also Published As
| Publication number | Publication date |
|---|---|
| CA2861858A1 (en) | 2013-07-04 |
| WO2013101599A1 (en) | 2013-07-04 |
| US20130168089A1 (en) | 2013-07-04 |
| RU2014131481A (en) | 2016-02-20 |
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