CN113882841B - Nano system composite CO2Method for improving oil well productivity through throughput - Google Patents
Nano system composite CO2Method for improving oil well productivity through throughput Download PDFInfo
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- 239000003129 oil well Substances 0.000 title claims abstract description 36
- 239000002131 composite material Substances 0.000 title description 6
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 69
- 239000000243 solution Substances 0.000 claims abstract description 60
- 238000002347 injection Methods 0.000 claims abstract description 40
- 239000007924 injection Substances 0.000 claims abstract description 40
- 238000000034 method Methods 0.000 claims abstract description 33
- 239000007788 liquid Substances 0.000 claims abstract description 29
- 239000002105 nanoparticle Substances 0.000 claims abstract description 22
- 238000013329 compounding Methods 0.000 claims abstract description 7
- 239000007787 solid Substances 0.000 claims abstract description 4
- 229910004298 SiO 2 Inorganic materials 0.000 claims description 18
- 239000002245 particle Substances 0.000 claims description 18
- NBVXSUQYWXRMNV-UHFFFAOYSA-N fluoromethane Chemical compound FC NBVXSUQYWXRMNV-UHFFFAOYSA-N 0.000 claims description 17
- 238000004519 manufacturing process Methods 0.000 claims description 17
- 239000004094 surface-active agent Substances 0.000 claims description 17
- KPUWHANPEXNPJT-UHFFFAOYSA-N disiloxane Chemical class [SiH3]O[SiH3] KPUWHANPEXNPJT-UHFFFAOYSA-N 0.000 claims description 11
- 239000011737 fluorine Substances 0.000 claims description 11
- 229910052731 fluorine Inorganic materials 0.000 claims description 11
- YCKRFDGAMUMZLT-UHFFFAOYSA-N Fluorine atom Chemical compound [F] YCKRFDGAMUMZLT-UHFFFAOYSA-N 0.000 claims description 10
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical group [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 6
- 125000000956 methoxy group Chemical group [H]C([H])([H])O* 0.000 claims description 6
- 239000006185 dispersion Substances 0.000 claims description 4
- 230000009471 action Effects 0.000 claims description 3
- -1 perfluorosiloxane Chemical group 0.000 claims description 3
- 238000003756 stirring Methods 0.000 claims description 3
- 238000001132 ultrasonic dispersion Methods 0.000 claims description 3
- 238000012937 correction Methods 0.000 claims description 2
- 125000001301 ethoxy group Chemical group [H]C([H])([H])C([H])([H])O* 0.000 claims description 2
- 239000003921 oil Substances 0.000 abstract description 55
- 239000010779 crude oil Substances 0.000 abstract description 27
- 239000011435 rock Substances 0.000 abstract description 27
- 230000008569 process Effects 0.000 abstract description 8
- 230000008021 deposition Effects 0.000 abstract description 7
- 230000035699 permeability Effects 0.000 description 12
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 6
- 239000013043 chemical agent Substances 0.000 description 6
- 230000000694 effects Effects 0.000 description 6
- 239000003607 modifier Substances 0.000 description 6
- 238000006073 displacement reaction Methods 0.000 description 4
- 238000000605 extraction Methods 0.000 description 4
- 229910002092 carbon dioxide Inorganic materials 0.000 description 3
- 239000001569 carbon dioxide Substances 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- 230000009467 reduction Effects 0.000 description 3
- 238000001179 sorption measurement Methods 0.000 description 3
- 238000005406 washing Methods 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
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- 238000011161 development Methods 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 239000002270 dispersing agent Substances 0.000 description 2
- 238000004090 dissolution Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 230000001502 supplementing effect Effects 0.000 description 2
- 230000002195 synergetic effect Effects 0.000 description 2
- 125000000129 anionic group Chemical group 0.000 description 1
- 239000003945 anionic surfactant Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 125000002091 cationic group Chemical group 0.000 description 1
- 239000003093 cationic surfactant Substances 0.000 description 1
- 230000005465 channeling Effects 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 230000001804 emulsifying effect Effects 0.000 description 1
- 125000001153 fluoro group Chemical group F* 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 244000005700 microbiome Species 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000007764 o/w emulsion Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 238000004062 sedimentation Methods 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 230000009469 supplementation Effects 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
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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
- C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
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Abstract
The invention discloses a method for improving the productivity of an oil well by compounding CO 2 throughput with a nano system, which comprises the following steps: (1) injecting a slug of the nano-solution: preparing a water-based nano solution with the solid content of 0.005% -0.01%, and injecting the water-based nano solution into a stratum from the annular space of an oil well oil sleeve; (2) Injecting liquid CO 2 slug: injecting a liquid CO 2 slug into the stratum from the oil well oil sleeve annulus, wherein the mass ratio of the injected CO 2 to the water-based nano solution is (1.5-2.2): 1; and (3) stopping injection and well stewing: after the injection of the liquid CO 2 is finished, closing the well to perform well shut-in, wherein the well shut-in time is 10-20 days. The nano particles can be adsorbed on the surface of rock, so that the nano particles are changed from oleophilic to oleophobic, the deposition of asphaltene is effectively prevented, the damage of asphaltene deposition to a reservoir layer in the process of spitting of CO 2 is greatly reduced, and the fluidity of crude oil is improved.
Description
Technical Field
The invention relates to the field of oil well yield increase in the oilfield development process, in particular to a method for improving the productivity of an oil well by compounding CO 2 throughput with a nano system.
Background
The low permeability oil reservoir has the characteristics of low pores, low permeability, low natural productivity, no water injection, no production and the like, and aims at the development difficulty of the low permeability oil field, and the carbon dioxide throughput becomes an effective yield increasing technology of the low permeability oil reservoir. The carbon dioxide huff and puff oil extraction technology is to inject a certain amount of carbon dioxide into an oil layer under a certain pressure, and after the oil layer is stewed for a period of time, the viscosity of crude oil can be obviously reduced, the volume of the crude oil is expanded, the relative permeability of the oil phase is improved, and the oil well yield is improved.
At present, with the increase of the extraction degree of each oil field, the stratum deficiency and the gas channeling are serious, the throughput effect of each old area block is poorer and worse, and the effective rate of measures is increased year by year, but the oil increase of a single well is reduced year by year, and the oil cost per ton is higher and higher. The CO 2 composite single well huff and puff can better play roles of washing oil, reducing viscosity, changing wettability and supplementing stratum energy by utilizing the synergistic effect of the CO 2 and other chemical components, so that the purpose of improving the huff and puff effect is achieved, and more attention is paid to petroleum workers.
CN 201410455336 discloses a microorganism and CO 2 compound single well huff and puff oil recovery method for thick oil wells, and the oil well suitable for the method needs to meet the following conditions: the oil well temperature is less than 100 ℃, the crude oil viscosity is less than 5000 Pa.s, the mineralization degree of stratum water is less than 50000mg/L, and the permeability is more than 50 multiplied by 10 -3μm2. Therefore, the method is not suitable for reservoirs with permeability less than 50 multiplied by 10 -3μm2, and the production increase of low permeability oil reservoirs is difficult to realize, and has certain technical limitations.
CN105952425A discloses a method for improving the recovery ratio of a common heavy oil reservoir by assisting CO 2 throughput with a chemical agent, and the method combines the chemical agent with CO 2, and exerts the synergistic effect of the chemical agent and the CO 2, so that after a plurality of rounds of throughput, the oil well can still maintain higher oil recovery ratio. The chemical agent related to the patent is viscosity-reducing chemical agent, and forms oil-in-water emulsion with common thickened oil, so that the tension of an oil-water interface is reduced, the flow resistance of crude oil during exploitation is reduced, but the related examples are in a laboratory stage, and the field application condition is not clarified.
The existing CO 2 composite huff and puff method can effectively improve the single well productivity of an oil well, but in the CO 2 'spitting' process, light components in crude oil are easy to extract from an oil reservoir, and heavy components such as asphaltene in the crude oil can be adsorbed on the surface of rock, so that the rock becomes oil wet, and the permeability is reduced. The research proves that the nano particles have the capability of stabilizing asphaltene precipitation, so that the nano particles are prevented from being adsorbed on the surface of rock, and in addition, the nano particles have the advantages of changing the wettability of the rock, reducing the tension of an oil-water interface, emulsifying and reducing the viscosity and the like due to the small size and the large specific surface area. Therefore, the nano system composite CO 2 throughput technology has important significance for improving throughput effect and improving single well productivity.
Disclosure of Invention
The invention aims to solve the technical problem of providing a method for improving the productivity of an oil well by compounding CO 2 throughput with a nano system. The preposed nano solution can reduce the adhesion work of oil drops and the rock surface, peel crude oil from the rock surface, simultaneously, nano particles can be adsorbed on the rock surface to change the oleophilicity into oleophobicity, thereby effectively preventing the deposition of asphaltene, greatly reducing the damage of the asphaltene deposition of CO 2 to a reservoir layer in the process of spitting and improving the fluidity of crude oil. In addition, the nano solution can cooperate with the subsequent CO 2 slug to play the roles of viscosity reduction, oil washing, dissolution expansion, extraction, formation energy supplementing and the like, and finally the purpose of improving the single well productivity of the oil well is achieved.
The invention is realized by the following technical scheme:
A method for improving the productivity of an oil well by compounding CO 2 throughput by a nano system comprises the following steps:
(1) Injecting a nano solution slug: preparing a water-based nano solution with the solid content of 0.005% -0.01%, and injecting the water-based nano solution into a stratum from the annular space of an oil well oil sleeve;
(2) Injecting liquid CO 2 slug: injecting a liquid CO 2 slug into a stratum from an oil well oil sleeve annulus, wherein the mass ratio of the injected liquid CO 2 (ground liquid) to the water-based nano solution is 1.5:1-2.2:1;
(3) Stopping injection and stewing well: after the injection of the liquid CO 2 is finished, closing the well to perform well shut-in, wherein the well shut-in time is 10-20 days.
In the well-stewing process of the step, the nano particles are chemically bonded with the surface of the rock, so that the adsorption force is high, crude oil is stripped from the surface of the rock, the nano particles can coarsely make the surface of the wall of the rock hole, a micro-nano binary structure is formed, a modifier with low surface energy in a nano system is modified on the micro-nano binary structure, the wettability of the near-wellbore area rock is changed from lipophilicity to lipophobicity, the oil-water seepage resistance is reduced, the subsequent CO 2 has the effects of dissolving and expanding with the crude oil, reducing viscosity and the like, and the mobility of the hard-to-drive residual oil in a rock reservoir is improved.
(4) And (3) well opening production: and after the well is closed, the oil well is opened for production. In the blowout process of the oil well, the oil well is regulated to be oleophobic near-wellbore zone, so that the deposition of heavy components such as asphaltene in crude oil can be effectively delayed, the fluidity of the crude oil is improved, and the CO 2 throughput effect is improved.
As a most preferable scheme, the water-based nano solution mainly comprises nano SiO 2 particles, a modifier, a dispersing agent and water, wherein the nano SiO 2 particles are nano SiO 2 particles prepared by a gas phase method, the modifier is fluorine-containing siloxane, the dispersing agent is fluorocarbon surfactant, and the water-based nano solution with the nano particle content of 0.005% -0.01% is prepared.
As a most preferred scheme, the water-based nano solution comprises the following components in percentage by mass: nano SiO 2 particle 0.005-0.010%, fluorine-containing siloxane 1-5%, fluorocarbon surfactant 0.1-0.5%, and water the rest.
As a most preferred embodiment, the nanoparticle size in the aqueous-based nanoparticle solution is less than 20nm. The nano particles with the size have good injectability to the hypotonic reservoir, enter the nano and micro-nano pore throats which cannot be accessed by the traditional chemical agents, strip more crude oil from the surface of the rock, adsorb the crude oil on the surface of the rock to form a micro-nano binary structure, modify low surface energy substances on the surface of the rock by utilizing the modifier, change the wettability of the rock, effectively prevent the deposition of asphaltene and improve the seepage capability of oil water.
As a most preferred scheme, the injection amount Q of the water-based nano-solution in the step (1) is: q=pi R 2 H Φβ;
Wherein: q-the injection amount of the nano solution, m 3; r is the treatment radius, m, and the value range is 10-20m; h, the effective thickness of an oil well production layer, m; phi-average porosity of the oil well production layer,%; beta-direction correction coefficient, dimensionless, with a value range of 0.8-1.0.
As a most preferable scheme, the injection amount of the water-based nano solution is 40-60 m 3/d, and the injection mode of day injection and night stop is adopted to spread the nano solution.
As a most preferred scheme, the mass ratio of CO 2 injected in the step (2) to the water-based nano solution is 2:1, and the injection speed is 20-30 t/d. During injection, dynamic adjustments may be made based on actual injection pressure conditions. If the pressure is lower, the injection quantity can be increased, and the injection period can be shortened; if special situations such as no injection or over-high injection pressure occur, the injection should be stopped in time.
As a most preferred embodiment, steps (1) - (4) may be repeated as desired.
As a most preferred scheme, the water-based nano solution comprises the following components in percentage by mass: nano SiO 2 particles 0.005%, fluorine-containing siloxane 3%, fluorocarbon surfactant 0.3% and the balance of water.
As a most preferable scheme, the nano SiO 2 particles are nano SiO 2 particles prepared by a gas phase method, and the SiO 2 content is not less than 99.8%; the fluorine-containing siloxane is one of perfluorosiloxane with a terminal methoxy group and a carbon chain length of 4-6; the chain length of the carbon chain of the fluorocarbon surfactant ranges from 6 to 10, the groups on the molecule of the fluorocarbon surfactant comprise 1 to 3 methoxy groups or ethoxy groups, the fluorocarbon surfactant is one or more of a cationic surfactant and an anionic surfactant, for example, the cationic fluorocarbon surfactant is one or more of a Capstone ST110 and a Capstone ST300 of Kemu company, and the anionic fluorocarbon surfactant is one or more of a Capstone FS-10, FS22, FS31, FS3100, FS50 and FS51 of Kemu company.
As a most preferred scheme, the water-based nano solution is prepared according to the following steps:
(1) Dripping fluorocarbon surfactant and fluorine-containing siloxane into water drop by drop, and mechanically stirring for 1h under the conditions of water bath at 50 ℃ and 300-2600 r/min.
(2) Dispersing nano SiO 2 particles into the dispersion liquid by an ultrasonic dispersion method, and oscillating for 10 minutes under the action of ultrasonic waves to obtain the water-based nano solution.
Compared with the prior art, the invention has the following beneficial effects:
(1) The method for improving the productivity of the oil well by compounding CO 2 throughput by the nano system can effectively solve the problem of the reduction of the oil production of a single well of a low-permeability oil reservoir.
(2) The particle size of the nano particles in the water-based nano solution is smaller than 20nm, and the water-based nano solution has good injectability to a hypotonic reservoir.
(3) The nano particles are chemically bonded with the rock surface, so that the adsorption force is high, crude oil on the rock surface can be efficiently stripped, and the oil washing efficiency is improved.
(4) The nano particles are adsorbed on the surface of the rock to form a micro-nano binary structure, and a modifier with low surface energy is modified, so that the wettability of a near-wellbore zone is changed from oleophilic to oleophobic, and the seepage resistance of crude oil is reduced; meanwhile, the sedimentation rate of the asphaltene can be effectively delayed, so that the deposition of the asphaltene in a near-wellbore zone in the process of spitting of CO 2 is effectively avoided, and the permeability of oil water is reduced.
(5) The water-based nano solution and the subsequent CO 2 slug cooperate to realize the equivalent use of viscosity reduction, dissolution expansion, extraction and formation energy supplementation, and finally realize the purpose of improving the single well productivity of the oil well.
Drawings
FIG. 1 is a graph of nanoparticle distribution testing in a water-based nanoparticle solution;
FIG. 2 is a graph comparing a crude oil contaminated core (left side) with a core (right side) after being immersed in a water-based nano-solution;
FIG. 3 is a schematic diagram of oil contact angle after water-based nano-solution is adsorbed on rock.
Detailed Description
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the technical solutions in the embodiments of the present invention will be clearly and completely described below, and it is apparent that the described embodiments are some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
Example 1
In a certain oilfield P8 well, the effective thickness of an oil layer is 7.1m, the average porosity is 25.4%, the average permeability is 16 multiplied by 10 -3μm2, the temperature of the oil layer is 50 ℃, the pressure of the oil layer is 10.41MPa, the density of ground crude oil is 0.9319t/m 3, the viscosity of the ground crude oil is 765.52mPa.s, and the solidifying point is 39 ℃.
The injection quantity Q of the nano solution is as follows: v=3.14R 2Hфβ＝3.14×7.12×10×0.254×0.8＝558m3, wherein: r takes on a value of 10 and beta takes on a value of 0.8. The injection amount of liquid CO 2 is 1116t calculated according to the gas-liquid ratio of 2:1.
The construction steps are as follows:
(1) Preparing a water-based nano solution with the solid content of nano particles of 0.005 percent: the water-based nano solution comprises the following components in percentage by mass: 0.005% of nano SiO 2 particles, 3% of fluorine-containing siloxane (the end group is methoxy group, the perfluorosiloxane with the carbon chain length of 6), 0.3% of fluorocarbon surfactant (the carbon chain length of 8, the groups on the molecule comprise 3 methoxy groups of fluorocarbon surfactant) and the balance of water. As shown in FIG. 1, the average particle size of nano SiO 2 particles in the water-based nano solution was 18.09nm.
The water-based nano solution is prepared according to the following steps:
1) Dripping fluorocarbon surfactant and fluorine-containing siloxane into water drop by drop, and mechanically stirring for 1h under the conditions of water bath at 50 ℃ and 300-2600 r/min.
2) Dispersing nano SiO 2 particles into the dispersion liquid by an ultrasonic dispersion method, and oscillating for 10 minutes under the action of ultrasonic waves to obtain the water-based nano solution.
(2) Injecting the water-based nano solution into the stratum through an oil sleeve annulus by adopting a pump truck, wherein the injection displacement is 60m 3/d, and injecting the water-based nano solution in a mode of stopping during day injection and night injection, so that the nano solution and crude oil of the stratum fully act. The nano particles are chemically bonded with the surface of the rock in the well stewing process, have stronger adsorption force, peel crude oil from the surface of the rock, the nano particles can coarsely make the surface of the wall of the rock hole, a micro-nano binary structure is formed, a modifier with low surface energy in a nano system is modified on the micro-nano binary structure, the wettability of the near-wellbore rock is changed from lipophilicity to lipophobicity, the oil-water seepage resistance is reduced, the subsequent CO 2 has the effects of dissolving and expanding with the crude oil, reducing viscosity and the like, and the mobility of the hard-to-drive residual oil in a rock reservoir is improved. Fig. 2 is a graph comparing a core contaminated with crude oil (left side) with a core soaked with a water-based nano solution (right side), and fig. 3 is a schematic diagram showing oil contact angle after the water-based nano solution is adsorbed on the rock.
(3) 1116T of liquid CO 2 is injected with 30t/d of injection displacement.
(4) Stopping injection and stewing the well for 20 days.
(5) And (5) well opening production.
The oil well production liquid before the operation of the P8 well of a certain oil field is 1.3t/d, the oil production is 0.1t/d, and the water content is 94.2%. After implementing nano system composite CO 2 huff and puff, the liquid yield and the oil yield of the P8 well are obviously increased, the water content is obviously reduced, the liquid yield of the oil well in the initial blowout stage is 6.1t/d, the oil yield is 3.7t/d, the water content is 40%, the daily liquid yield after the oil well machine is pumped is 6.6t/d, the daily oil yield is 2.1t/d, the water content is 68.1%, the average daily oil increment of a single well is 1.5t/d, the cumulative oil increment is 675t, the effective period is 15 months, and the continuous effective period is realized.
Example 2
In a certain oilfield P11 well, the effective thickness of an oil layer is 4.8m, the average porosity is 24.3%, the average permeability is 27 multiplied by 10 -3μm2, the temperature of the oil layer is50 ℃, the pressure of the oil layer is 10.41MPa, the density of ground crude oil is 0.9457t/m < 3 >, the viscosity of the ground crude oil is 896.62mPa.s, and the solidifying point is 40 ℃.
The injection quantity Q of the nano solution is as follows: v=3.14R 2Hфβ＝3.14×4.82×20×0.243×0.8＝281m3, wherein: r takes the value of 20 and beta takes the value of 0.8. The injection amount of liquid CO 2 is 563t according to the gas-liquid ratio of 2:1.
The construction steps are as follows:
(1) The same water-based nano-solution as in example 1 was prepared.
(2) Injecting the water-based nano solution into the stratum through an oil sleeve annulus by adopting a pump truck, wherein the injection displacement is 40m 3/d, and injecting the water-based nano solution in a mode of stopping during day injection and night injection, so that the nano solution and crude oil of the stratum fully act.
(3) And injecting 5636t liquid CO 2 with injection displacement of 20t/d.
(4) Stopping injection and stewing the well for 18 days.
(5) And (5) well opening production.
The oil well production liquid before the operation of the P11 well of a certain oil field is 2.4t/d, the oil production is 1.3t/d, and the content is 44.0 percent. After implementing nano system composite CO 2 huff and puff, the liquid yield and oil yield of the P8 well are obviously increased, the water content is obviously reduced, the oil yield of the oil well in the initial blowout stage is 5.4t/d, the oil yield is 4.4t/d, the water content is 19%, the daily liquid yield of the oil well machine is 6.1t/d, the daily oil yield is 2.9t/d, the water content is 52%, the average daily oil increment of a single well is 1.2t/d, the cumulative oil increment is 432t, the effective period is 12 months, and the continuous effective period is realized.
The foregoing has shown and described the basic principles, principal features and advantages of the invention. It will be understood by those skilled in the art that the present invention is not limited to the embodiments described above, and that the above embodiments and descriptions are merely illustrative of the principles of the present invention, and various changes and modifications may be made therein without departing from the spirit and scope of the invention, which is defined by the appended claims. The scope of the invention is defined by the appended claims and equivalents thereof.
Claims (7)
1. A method for improving the productivity of an oil well by compounding CO 2 throughput by a nano system is characterized by comprising the following steps:
(1) Injecting a nano solution slug: preparing a water-based nano solution with the solid content of 0.005% -0.01%, and injecting the water-based nano solution into a stratum from the annular space of an oil well oil sleeve;
(2) Injecting a ground liquid CO 2 slug: injecting a ground liquid CO 2 slug into a stratum from an oil well oil sleeve annulus, wherein the mass ratio of the injected ground liquid CO 2 to the water-based nano solution is 1.5:1-2.2:1;
(3) Stopping injection and stewing well: after the injection of the ground liquid CO 2 is finished, closing the well to perform well shut-in, wherein the well shut-in time is 10-20 days;
(4) And (3) well opening production: after the well is closed, the well is opened for production;
The water-based nano solution comprises the following components in percentage by mass: 0.005-0.010% of nano SiO 2 particles, 1-5% of fluorine-containing siloxane, 0.1-0.5% of fluorocarbon surfactant and the balance of water; the fluorine-containing siloxane is one of a terminal methoxy group and a perfluorosiloxane with a carbon chain length of 4-6;
The chain length of the carbon chain of the fluorocarbon surfactant ranges from 6 to 10, and the groups on the molecule of the fluorocarbon surfactant comprise 1 to 3 methoxy groups or ethoxy groups;
The injection quantity Q of the water-based nano solution is as follows: q=pi R 2 H Φβ;
Wherein: q-the injection amount of the nano solution, m 3; r is the treatment radius, m, and the value range is 10-20m; h, the effective thickness of an oil well production layer, m; phi-average porosity of the oil well production layer,%; beta-direction correction coefficient, dimensionless, with a value range of 0.8-1.0.
2. The method of claim 1, wherein the nanoparticle size in the aqueous-based nanoparticle solution is less than 20nm.
3. The method according to claim 2, wherein the injection amount of the water-based nano solution is 40-60 m 3/d, and the nano solution is spread by adopting an injection mode of stopping day injection and night.
4. The method of claim 1, wherein the mass ratio of CO 2 injected in step (2) to the water-based nano-solution is 2:1, and the injection speed is 20-30 t/d.
5. The method according to claim 1, wherein the water-based nano-solution comprises the following components in percentage by mass: nano SiO 2 particles 0.005%, fluorine-containing siloxane 3%, fluorocarbon surfactant 0.3% and the balance of water.
6. The method of claim 1, wherein the nano SiO 2 particles are nano SiO 2 particles prepared by a gas phase method, and the SiO 2 content is not less than 99.8%.
7. The method of claim 1, wherein the aqueous-based nano-solution is prepared by:
(1) Dripping fluorocarbon surfactant and fluorine-containing siloxane into water dropwise, and mechanically stirring for 1h under the conditions of water bath at 50 ℃ and 300-2600 r/min to obtain a dispersion liquid;
(2) Dispersing nano SiO 2 particles into the dispersion liquid obtained in the step (1) by an ultrasonic dispersion method, and oscillating for 10 minutes under the action of ultrasonic waves to obtain the water-based nano solution.
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