CN113622893B - Reservoir reforming method - Google Patents

Reservoir reforming method Download PDF

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Publication number
CN113622893B
CN113622893B CN202010384351.2A CN202010384351A CN113622893B CN 113622893 B CN113622893 B CN 113622893B CN 202010384351 A CN202010384351 A CN 202010384351A CN 113622893 B CN113622893 B CN 113622893B
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reservoir
acid
parts
agent
working fluid
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CN113622893A (en
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刘洪涛
袁学芳
黄龙藏
周福建
栾婷婷
任登峰
彭芬
刘会锋
任慧宁
李永坡
谢宇
张超
谭艳新
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Petrochina Co Ltd
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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
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
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    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/602—Compositions for stimulating production by acting on the underground formation containing surfactants
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    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/62—Compositions for forming crevices or fractures
    • C09K8/66—Compositions based on water or polar solvents
    • C09K8/68—Compositions based on water or polar solvents containing organic compounds
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    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/62—Compositions for forming crevices or fractures
    • C09K8/66—Compositions based on water or polar solvents
    • C09K8/68—Compositions based on water or polar solvents containing organic compounds
    • C09K8/685—Compositions based on water or polar solvents containing organic compounds containing cross-linking agents
    • 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
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/62—Compositions for forming crevices or fractures
    • C09K8/72—Eroding chemicals, e.g. acids
    • C09K8/74—Eroding chemicals, e.g. acids combined with additives added for specific purposes
    • 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
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/84—Compositions based on water or polar solvents
    • C09K8/86—Compositions based on water or polar solvents containing organic compounds
    • C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • C09K8/885—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
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    • 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
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/84—Compositions based on water or polar solvents
    • C09K8/86—Compositions based on water or polar solvents containing organic compounds
    • C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • C09K8/887—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
    • C—CHEMISTRY; METALLURGY
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    • 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
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/84—Compositions based on water or polar solvents
    • C09K8/86—Compositions based on water or polar solvents containing organic compounds
    • C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • C09K8/90—Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
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    • 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
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/84—Compositions based on water or polar solvents
    • C09K8/86—Compositions based on water or polar solvents containing organic compounds
    • C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • C09K8/90—Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
    • C09K8/905—Biopolymers
    • 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
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
    • 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
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/32—Anticorrosion additives
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
    • Y02A10/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE at coastal zones; at river basins
    • Y02A10/40—Controlling or monitoring, e.g. of flood or hurricane; Forecasting, e.g. risk assessment or mapping

Abstract

The invention relates to a reservoir reconstruction method, which comprises the following steps: 1) At 0.2-15m 3 The displacement of/min is injected into the reservoir for 20-300m 3 Is a working fluid of (2); 2) At 1-10m 3 The displacement per min is 5-100m into the reservoir 3 A mixture of a working fluid and a steering agent; 3) At 1.5-15m 3 The displacement per min is injected into the reservoir for 30-500m 3 A mixture of a working fluid and a proppant or an acid fluid; 4) And (5) injecting the working solution again for displacement. According to the invention, partial microcracks in the reservoir are activated by the working fluid, and the diversion agent enters the microcracks to reduce the fluid loss of the working fluid, so that the working fluid can further activate the microcracks to form a fracture network, and oil and gas in the reservoir seep outwards through the fracture network, thereby improving the yield of oil and gas exploitation.

Description

Reservoir reforming method
Technical Field
The invention relates to the technical field of petroleum and natural gas exploitation, in particular to a reservoir transformation method.
Background
With the rapid development of industry, conventional oil and gas resources cannot meet the development requirements, so that development and utilization of unconventional oil and gas resources are urgently needed. Unconventional oil and gas resources refer to oil and gas resources which can not obtain natural industrial yield by using the traditional technology, can not economically exploit continuous or quasi-continuous aggregation by using new technology to improve the permeability of a reservoir or the viscosity of fluid and the like. In particular, the hydrocarbon resources may be divided into unconventional petroleum resources and unconventional natural gas resources such as heavy oil, tight sandstone gas, coalbed methane, shale gas, and natural gas hydrates, among others, which are typically stored in a formation of complex geological structure, which may be referred to as a reservoir. The reservoir has natural fractures therein, which can be divided into micro-fractures, which are the primary percolation pathways connecting the matrix areas (oil and gas containing areas) with the artificial fractures, and developing fractures, through which the oil and gas of the matrix areas can leak out. However, because the reservoir structure of unconventional hydrocarbon resources is dense, making it difficult for oil and gas in the matrix region to seep through natural fractures in the reservoir, it is desirable to activate micro-fractures in the natural fractures to increase the permeability of the fluid in the matrix region to increase the production of hydrocarbon production.
Currently, methods for the modification of unconventional hydrocarbon-based reservoirs typically employ working fluids containing high molecular polymers, slickwater or linear colloidal systems to improve the permeability of natural fractures in the reservoir. While working fluid containing high molecular polymer can not activate micro-cracks in the reservoir, while working fluid containing slickwater and linear colloid can activate micro-cracks in the reservoir, the working fluid entering the micro-cracks can be subjected to a great amount of fluid loss along with the increase of the number of activated micro-cracks in the reservoir, so that the capability of the working fluid for activating the micro-cracks is limited, and the oil and gas exploitation yield can not meet the requirement.
Therefore, there is an urgent need to develop a reservoir reformation method that increases the production of oil and gas in a reservoir by reducing the fluid loss.
Disclosure of Invention
Aiming at the problems in the prior art, the invention provides a reservoir reconstruction method, which comprises the steps of injecting a working fluid containing specific components to activate microcracks in a reservoir, and adopting a steering agent to reduce the fluid loss of the working fluid entering the microcracks, so that the working fluid further activates the microcracks to form a fracture network with better permeability, thereby improving the yield of oil and gas exploitation in the reservoir.
The invention firstly provides a reservoir reconstruction method, which comprises the following steps:
1) At 0.2-15m 3 The displacement of/min is injected into the reservoir for 20-300m 3 Is a working fluid of (2);
2) At 1-10m 3 A displacement of/min is injected into the reservoir of 5-100m 3 The weight ratio of the working fluid to the steering agent is (100.021-100.5): (0.001-1), and the particle size of the steering agent is 0.25-0.425mm;
3) At 1.5-15m 3 A displacement of/min is injected into the reservoir for 30-500m 3 A mixture of a working fluid and a proppant or an acid fluid;
4) Reinjecting the working solution for displacement;
the working solution comprises the following components in parts by weight: 100 parts of water, 0.001-1.0 part of drag reducer, 0.01-2.0 parts of demulsifier and 0.01-2.0 parts of cleanup additive.
In some embodiments, the demulsifier is selected from one or both of a nonionic surfactant and a cationic surfactant; the cleanup additive is selected from fluorosurfactants.
In some embodiments, the diverter is a degradable diverter.
In some embodiments, the degradable diverting agent is selected from at least one of a fiber, a modified fiber, a polyester particle, and a crosslinked polymer particle.
In some embodiments, the steps 1) -2) are repeated before step 3) is performed.
In some embodimentsIn the step 2), the propping agent is selected from one or two of quartz sand and ceramsite, and the adding amount of the propping agent is 50-1000kg/m based on the volume of the working fluid 3 。
In some embodiments, when the reservoir is a tight sandstone reservoir, the acid is selected from the group consisting of organic earth acids.
In some embodiments, the organic earth acid comprises the following components in parts by weight: 100 parts of mixed acid liquor, 1-4 parts of viscosity stabilizer, 2-7 parts of corrosion inhibitor, 1-4 parts of cleanup additive, 1-4 parts of iron ion stabilizer, 1-4 parts of demulsifier, 0.2-0.4 part of gelling agent and 3-6 parts of methanol; wherein the mixed acid solution comprises hydrochloric acid, acetic acid and water.
In some embodiments, when the reservoir is a tight carbonate reservoir, the acid is selected from the group consisting of gelled acid, ground cross-linking acid, clean diverting acid, and temperature controlled viscosified acid.
In some embodiments, the gelled acid comprises the following components in parts by weight: 100 parts of hydrochloric acid, 0.3-1 part of gelatinizer, 1-4 parts of corrosion inhibitor, 0.5-1 part of demulsifier, 0.5-2 parts of iron ion stabilizer and 0.5-1 part of cleanup additive;
the ground crosslinking acid comprises the following components in percentage by weight: 15-25% of hydrochloric acid, 0.5-1% of thickening agent, 0.5-5% of demulsifier, 0.5-5% of cleanup additive, 1-5% of corrosion inhibitor, 0.5-5% of iron ion stabilizer, 0.5-5% of regulator, 0.5-1% of cross-linking agent and the balance of water;
the cleaning diverting acid comprises the following components in percentage by weight: 15-25% of hydrochloric acid, 5-15% of steering acid main agent, 0.1-1% of resistance reducing agent, 1-5% of corrosion inhibitor and the balance of water;
the temperature-control variable viscosity acid comprises the following components in percentage by weight: 20% hydrochloric acid, 0.6-1.2% gelatinizer, 1-6% corrosion inhibitor, 1-4% cleanup additive, 1-4% demulsifier, 1-4% iron ion stabilizer, 0.5-0.8% activator and the balance water.
In some embodiments, in the composition of the gelled acid, the gelling agent is selected from acid-fast cationic polymers, the corrosion inhibitor is selected from aldehyde-ketone amine polymers, and the demulsifier is selected from one or both of nonionic surfactants and cationic surfactants; the cleanup additive is selected from fluorosurfactants;
in the composition of the organic earth acid, the viscosity stabilizer is selected from potassium salt or quaternary ammonium salt, the corrosion inhibitor is selected from aldehyde ketone amine condensate, the cleanup additive is selected from fluorine-containing surfactant, the iron ion stabilizer is composed of an iron complexing agent and an iron reducing agent, the demulsifier is selected from one or two of nonionic surfactant and cationic surfactant, and the gelling agent is selected from acid-resistant cationic polymer.
The embodiment of the invention has at least the following beneficial effects:
according to the reservoir reconstruction method provided by the invention, the microcracks in the reservoir are activated by injecting the working solution containing specific components, and then the diversion agent is injected into the microcracks to reduce the fluid loss of the working solution, so that the working solution can further activate the microcracks to form a crack network with better permeability, and petroleum and natural gas in the reservoir are exuded outwards through the crack network, so that the yield of oil and gas exploitation in the reservoir can be improved;
Detailed Description
The invention firstly provides a reservoir reconstruction method, which comprises the following steps:
1) At 0.2-15m 3 The displacement of/min is injected into the reservoir for 20-300m 3 Activating a portion of the microcracks in the reservoir;
2) At 1-10m 3 The displacement per min is 5-100m into the reservoir 3 The weight ratio of the working solution to the steering agent is (100.021-100.5): (0.001-1), and the grain diameter of the steering agent is 0.25-0.425mm; the fluid loss of the working fluid can be reduced through the steering agent, so that more microcracks can be activated by the working fluid;
3) At 1.5-15m 3 A displacement of/min is injected into the reservoir for 30-500m 3 A mixture of a working fluid and a proppant or an acid fluid; the mixture of the working solution and the propping agent or the acid solution is injected, so that the micro-cracks can be propped or etched, and the permeability and the stability of the micro-cracks are further improved, and the penetration and the output of oil gas are further improved;
4) Injecting the working solution again for displacement, namely pushing the mixture of the working solution and the propping agent or the acid liquor into the deep part of the reservoir through the working solution so as to remove the deep pollution zone and dredge the fracture network;
the working solution comprises the following components in parts by weight: 100 parts of water, 0.001-1 part of drag reducer, 0.01-2 parts of demulsifier and 0.01-2 parts of cleanup additive.
According to the reservoir reconstruction method provided by the invention, the drag reducer, the demulsifier, the cleanup additive and the water are reasonably configured by adopting the working solution, so that the components are synergistic, and the working solution can activate microcracks in the reservoir and simultaneously reduce the damage to the reservoir and the transportation cost. When the number of the micro-cracks is increased, a large amount of working fluid entering the micro-cracks is lost, so that new micro-cracks cannot be activated continuously, the addition of the steering agent can reduce the loss of the working fluid in the micro-cracks, so that the working fluid can be helped to activate the new micro-cracks to form a crack network, and the pressure of a pump for conveying the working fluid and the steering agent is increased due to the generation of the new micro-cracks. In order to enable the diverter to enter the microcrack to reduce the fluid loss of the working fluid, the weight ratio of the working fluid to the diverter needs to be controlled in the step of injecting the working fluid and the diverter to be (100.021-100.5): (0.001-1), and the particle size of the diverting agent should be 0.25-0.425mm. Rock types of reservoirs are mainly classified into sandstone and carbonate rock, and sandstone reservoirs are usually used for supporting cracks by injecting a mixture of working fluid and propping agent, and acid liquor can be injected sometimes for acid etching; carbonate reservoirs are commonly acid etched into the fracture by injection of acid, both of which can improve the permeability and stability of the fracture. Due to the formation of the fracture network, oil and gas in the matrix region can seep out to the fracture network at a shorter distance, and due to the shortened flowing distance, the seepage resistance is reduced, so that the oil and gas in the matrix region can easily seep out to the shaft through the fracture network, and the yield of oil and gas exploitation can be improved.
In the reservoir reforming method of the present invention, the working fluid is injected into the reservoir through the pipe by the pump, and during the process of the working fluid being conveyed in the pipe, the working fluid is turbulent due to the pressure of the pump, and the turbulent flow increases the flow resistance of the working fluid, so that more power is required to be consumed to convey the working fluid, resulting in an increase in conveying cost. The addition of the drag reducer can reduce the flow resistance of the working solution, thereby reducing the pumping pressure and the transportation cost. The particular choice of drag reducer is not particularly critical and in particular embodiments of the present invention, the drag reducer may be selected from FR-800, a company of the field chemistry, ltd, of the beijing family.
In addition, the working fluid passes through the reservoir at a higher speed to form emulsion with the crude oil in the reservoir, which may cause emulsification damage, resulting in reduced permeability of the reservoir, and seriously affecting the flowback speed of the working fluid and the oil well yield. The scheme of the invention can prevent and eliminate emulsion formed by the working solution in the reservoir by matching with the addition of the demulsifier, and effectively improve the flowback speed. In some embodiments of the present invention, the demulsifier may be selected from one or both of a nonionic surfactant and a cationic surfactant. Among them, the nonionic surfactant may be a condensate of alkylphenol with ethylene oxide, such as commercially available OP-4, OP-6, OP-7, OP-9, OP-10, OP-15, OP-20 and OP-40; cationic surfactants are well known to those skilled in the art and include, for example, cationic surfactants such as quaternary ammonium salts and pyridinium salts. In a specific embodiment of the present invention, the demulsifier is FRZ-4 from Beijing family Maishi oilfield chemical technology Co.
In addition, in order to enable smooth injection of the working fluid into the reservoir, a drainage aid is added to the composition to reduce the interfacial tension of the fluid. The drainage aid may be selected from fluorosurfactants such as perfluorooctyl polyoxyethylene ether nonionic surfactants. In some embodiments of the invention, the cleanup additive is selected from HSC-25 of the Beijing family Maishi oilfield chemical technology Co.
The invention also provides a preparation method of the working solution, which comprises the following steps: and mixing the components of the working solution according to a certain proportion to obtain the working solution.
As previously described, in the reservoir retrofitting methods of the present invention, the diverter may reduce fluid loss of the working fluid. In the step of injecting the working fluid and the steering agent, if the specific gravity of the steering agent exceeds the above range, the steering agent cannot enter the microcrack, and thus the effect of reducing the fluid loss cannot be achieved. Meanwhile, the grain diameter of the steering agent is required to be in the range of 0.25mm-0.425mm because the width of the microcrack is smaller.
In the reservoir retrofitting methods of the present invention, the diverter may be selected from water-soluble diverter or oil-soluble diverter. In particular, the water-soluble diverter may be selected from fine grade benzoic acid or benzoate; the oil-soluble diverter may be selected from a mixture of hydrocarbons and resins.
In some embodiments of the invention, the diverter may be further selected from degradable diverters that can self-degrade at the appropriate reservoir temperature after reservoir intervention without the need for cleanup or removal treatments. The above-mentioned degradable diverter may be selected from at least one of fibers, modified fibers, polyester particles and crosslinked polymer particles, for example, engineering fibers FCL, modified fibers DCF-1, flow diverter SR-3 (crosslinked polymer particles) or fracturing fluid diverter polyester particles DCF-2 of the beijing family of the company of the field chemical technology, ltd.
In the reservoir retrofitting method of the present invention, steps 1) -2) may be repeated prior to step 3), which may help to further increase the production of hydrocarbon production. In a specific embodiment of the present invention, steps 1) -2) may be repeated 1-6 times, wherein the displacement and total amount of working fluid are not required to be consistent with the aforementioned steps 1) -2) when steps 1) -2) are repeated, and suitable displacement and total amount may be selected according to actual needs.
In the reservoir reconstruction method, the step 2) can adopt the mixture of the propping agent and the working fluid to be injected into the cracks of the reservoir, and plays a role in supporting the cracks from being closed due to stress release, so that the permeability and the stability of the cracks are improved, and the yield of oil and gas exploitation can be improved. In a specific embodiment of the invention, the propping agent is selected from one or two of quartz sand and ceramsite, and the addition amount of the propping agent is 50-1000kg/m based on the volume of the injected working fluid 3 。
In the reservoir reconstruction method, the step 2) can also adopt acid liquor to be injected into the cracks of the reservoir, and the purpose of improving the permeability and stability of the cracks is achieved through acid etching of the cracks, so that the yield of oil and gas exploitation can be improved.
In some embodiments of the invention, the acid is selected from acid systems conventional in the art, such as gelled acid, ground crosslinking acid, clean diverting acid, temperature controlled variable mucic acid, emulsified acid, foamed acid, or organic earth acid, among others.
Different reservoir types require corresponding acid solutions for acid etching to provide better permeability and stability to the fracture. In the reservoir reforming method of the present invention, when the reservoir is a tight carbonate reservoir, in order to be able to improve the permeability and stability of the fracture, an acid solution is usually injected, and the acid solution is selected from gelled acid, ground cross-linking acid, clean diverting acid or temperature-controlled viscosified acid; when the reservoir is a tight sandstone reservoir, it is common to inject a mixture of proppants and working fluids, or an organic acid solution, in order to be able to increase the permeability and stability of the fracture.
In a specific embodiment of the invention, when the reservoir is a tight carbonate reservoir, the gelled acid is selected to comprise the following components in parts by weight: 100 parts of hydrochloric acid, 0.3-1 part of gelatinizer, 1-4 parts of corrosion inhibitor, 0.5-1 part of demulsifier, 0.5-2 parts of iron ion stabilizer and 0.5-1 part of cleanup additive.
Further, in the above-mentioned composition of the gelled acid, the gelling agent may be an acid-resistant cationic polymer, which may be formed by mixing two or more compounds of olefins, sulfonic acid-based organic substances and organic amine salts, for example, acrylamide, 2-acrylamido-2-methylpropanesulfonic acid, 2-acrylamido-hexadecanesulfonic acid and dimethyldiallylammonium chloride copolymer, or a copolymer of acrylamide, 2-acrylamido-2-methylpropanesulfonic acid and trimethylammonium chloride, or a copolymer of styrene, methylstyrene and trimethylammonium chloride. In a specific embodiment of the present invention, the gelled acid may be KMS-50, a company of Beijing family Maishi oilfield chemical technologies; the corrosion inhibitor may be an aldehyde-ketone amine condensate, such as KMS-6 of beijing, the company of the field chemistry of the field of the family of the america, the company of the technology of the field chemistry; the demulsifier may be selected from one or both of a nonionic surfactant and a cationic surfactant. Among them, the nonionic surfactant may be a condensate of alkylphenol with ethylene oxide, such as commercially available OP-4, OP-6, OP-7, OP-9, OP-10, OP-15, OP-20 and OP-40; cationic surfactants are well known to those skilled in the art and include, for example, cationic surfactants such as fatty amine hydrochlorides, quaternary ammonium salts, pyridinium salts, and the like. In a specific embodiment of the present invention, the demulsifier may be FRZ-4 from Beijing family Maishi oilfield chemistry, inc.; iron ion stabilizers are well known to those skilled in the art, such as KMS-7, a technology Co., ltd. Of the oil field chemistry of the Beijing family; the cleanup additive may be a fluorosurfactant such as perfluorooctyl polyoxyethylene ether nonionic surfactant. In some embodiments of the invention, the cleanup additive is selected from HSC-25 of the Beijing family Maishi oilfield chemical technology Co.
When the reservoir reformation is implemented according to the method of the invention, the acid liquor system can be selected according to a common dividing mode in the field, and prepared by self-mixing of the determined components, and can also be directly purchased commercially.
In a specific embodiment of the invention, when the reservoir is a tight carbonate reservoir, the selected surface cross-linking acid comprises the following components in weight percent: 15-25% of hydrochloric acid, 0.5-1% of thickening agent, 0.5-5% of demulsifier, 0.5-5% of cleanup additive, 1-5% of corrosion inhibitor, 0.5-5% of iron ion stabilizer, 0.5-5% of regulator, 0.5-1% of cross-linking agent and the balance of water.
Further, in the above-mentioned components of the ground cross-linking acid, the thickener may be KMS-30A of Beijing family Maishi oilfield chemical technology Co., ltd; the demulsifier can be FRZ-4 of Beijing family Maishi oilfield chemical agent technology Co., ltd; the cleanup additive may be HSC-25 of the Beijing family Maishi oilfield chemical technology Co., ltd; the corrosion inhibitor can be KMS-6 of Beijing family Maishi oilfield chemical agent technology Co., ltd; the iron ion stabilizer may be KMS-7 of Beijing family Maishi oilfield chemical agent technology Co., ltd; the regulator may be KMS-30 of Beijing family Maishi oilfield chemical technology Co., ltd; the cross-linking agent may be KMS-30B of Beijing family Maishi oilfield chemical technology Co.
When the reservoir reformation is implemented according to the method of the invention, the acid liquor system can be selected according to a common dividing mode in the field, and prepared by self-mixing of the determined components, and can also be directly purchased commercially.
In a specific embodiment of the invention, when the reservoir is a tight carbonate reservoir, the selected clean diverting acid comprises the following components in weight percent: 15-25% of hydrochloric acid, 5-15% of steering acid main agent, 0.1-1% of resistance reducing agent, 1-5% of corrosion inhibitor and the balance of water.
Further, in the above-described clean diverting acid composition, the diverting acid base may be selected from oleamide propyl betaine (VES), and in one embodiment of the present invention, the diverting acid base is DCA-1 of the beijing family of the company of the field chemical technology, ltd; the resistance reducing agent can be KMS-50 of Beijing family Maishi oilfield chemical agent technology Co., ltd; the corrosion inhibitor can be DCA-6 of Beijing family Maishi oilfield chemical agent technology Co.
When the reservoir reformation is implemented according to the method of the invention, the acid liquor system can be selected according to a common dividing mode in the field, and prepared by self-mixing of the determined components, and can also be directly purchased commercially.
In a specific embodiment of the invention, when the reservoir is a tight carbonate reservoir, the selected temperature controlled variable mucic acid comprises the following components in weight percent: 20% hydrochloric acid, 0.6-1.2% gelatinizer, 1-6% corrosion inhibitor, 1-4% cleanup additive, 1-4% demulsifier, 1-4% iron ion stabilizer, 0.5-0.8% activator and the balance water.
Further, in the above composition of temperature-controlled variable mucic acid, the gelling agent may be KMS-50 of Beijing family Maishi oilfield chemical technology Co., ltd; the corrosion inhibitor can be KMS-6 of Beijing family Maishi oilfield chemical agent technology Co., ltd; the cleanup additive may be HSC-25 of the Beijing family Maishi oilfield chemical technology Co., ltd; the demulsifier can be FRZ-4 of Beijing family Maishi oilfield chemical agent technology Co., ltd; the iron ion stabilizer may be KMS-7 of Beijing family Maishi oilfield chemical agent technology Co., ltd; the activator may be KMS-50H of Beijing family Maishi oilfield chemical technology Co.
When the reservoir reformation is implemented according to the method of the invention, the acid liquor system can be selected according to a common dividing mode in the field, and prepared by self-mixing of the determined components, and can also be directly purchased commercially.
In a specific embodiment of the invention, when the reservoir is a tight sandstone reservoir or a tight carbonate reservoir, the organic earth acids selected comprise the following components in parts by weight: 100 parts of mixed acid liquor, 1-4 parts of viscosity stabilizer, 2-7 parts of corrosion inhibitor, 1-4 parts of cleanup additive, 1-4 parts of iron ion stabilizer, 1-4 parts of demulsifier, 0.2-0.4 part of gelling agent and 3-6 parts of methanol; wherein the mixed acid solution comprises hydrochloric acid, acetic acid and water.
Further, in the above organic acid components, the mixed acid liquid comprises the following components in percentage by weight: 9% hydrochloric acid, 3% acetic acid and 88% water; the mixed acid liquid comprises hydrochloric acid, acetic acid and water, and also comprises hydrofluoric acid, wherein the mixed acid liquid comprises the following components in percentage by weight: 7.9% hydrochloric acid, 2.6% acetic acid, 1.7% hydrofluoric acid, and 87.8% water; the viscosity stabilizer can be potassium salt or quaternary ammonium salt; the corrosion inhibitor may be an aldehyde-ketone amine condensate, such as KMS-6 of beijing, the company of the field chemistry of the field of the family of the america, the company of the technology of the field chemistry; the cleanup agent may be a fluorosurfactant, such as HSC-25 from the company beijing family of the company maishi oilfield chemistry technology limited; the iron ion stabilizer consists of an iron complexing agent and an iron reducing agent, such as KMS-7 of Beijing family Maishi oilfield chemical technologies Co., ltd; the demulsifier may be selected from one or both of condensates of alkylphenols with ethylene oxide and cationic surfactants, such as FRZ-4 from beijing, the company of the field chemistry, inc; the gelling agent may be an acid resistant cationic polymer such as KMS-50, a company of the Beijing family Maishi oilfield chemical technology Co.
When the reservoir reformation is implemented according to the method of the invention, the acid liquor system can be selected according to a common dividing mode in the field, and prepared by self-mixing of the determined components, and can also be directly purchased commercially.
In the reservoir modification process of the present invention, the foamed and emulsified acids may employ acids well known to those skilled in the art.
In a specific embodiment of the invention, the displacement and total amount of the working fluid injected in the step 4) are adjusted according to the condition that the mixture of the working fluid and the propping agent or the acid liquor is injected into the reservoir in the step 3), so that the mixture of the working fluid and the propping agent or the acid liquor is promoted to enter the deep part of the reservoir to remove the pollution zone, and a fracture network is dredged, so that the subsequent yield increasing operation is facilitated.
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 in the following in conjunction with the embodiments of the present invention, 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.
The reservoirs modified in examples 1-3 below were tight sandstone reservoirs and the reservoirs modified in examples 4-8 were tight carbonate reservoirs, both types of reservoirs containing significant amounts of oil and gas.
Example 1
The embodiment provides a reservoir reconstruction method, wherein liquid injected into a reservoir is pumped, and the method specifically comprises the following steps:
1) At 2m 3 A displacement of/min injects 80m into the reservoir 3 Is a working fluid of (2);
2) At 1.9m 3 Displacement of/min 40m injection into reservoir 3 The weight of the steering agent is 0.5 percent of the weight of the working fluid, and the particle size of the steering agent is 0.25-0.425mm; when the above mixture is injected into the reservoir, the pump pressure rises by 4.3MPa;
3) At 2m 3 Displacement of/min 45m injection into reservoir 3 Is a working fluid of (2);
4) At 1.8m 3 Displacement of/min 40m injection into reservoir 3 The weight of the steering agent is 0.5 percent of the weight of the working fluid, and the grain diameter of the steering agent is 0.25-0.425mm; when the mixture is injectedAfter the reservoir, the pump pressure increased by 1.1MPa;
5) At 1.9m 3 Displacement per min 120m injection into the reservoir 3 Organic earth acids of (2);
6) At 1.5m 3 Displacement injection of 50 m/min 3 Pushing organic acid into the deep part of the reservoir to remove the deep pollution zone and dredge the fracture network.
Wherein, the working solution comprises the following components in parts by weight: mixing 100 parts of water, 0.1 part of drag reducer FR-800,0.5 part of demulsifier FRZ-4 and 0.5 part of cleanup additive HSC-25 to obtain a working solution;
the steering agent is engineering fiber FCL, the fiber FCL is pretreated to set granularity, and the degradation rate of the engineering fiber FCL can reach more than 95% when the temperature of a reservoir is about 90 ℃.
The organic earth acid comprises the following components in parts by weight: 100 parts of water, 9 parts of hydrochloric acid, 3 parts of acetic acid, 2 parts of hydrofluoric acid, 2 parts of potassium chloride, 4 parts of corrosion inhibitor KMS-6, 1 part of cleanup additive HSC-25, 2 parts of ferric ion stabilizer KMS-7, 0.3 part of gelatinizer KMS-50, 5 parts of methanol and 1 part of demulsifier FRZ-4 are mixed to obtain the organic soil acid.
Example 2
The embodiment provides a reservoir reconstruction method, wherein liquid injected into a reservoir is pumped, and the method specifically comprises the following steps:
1) At 15m 3 Displacement of/min 300m injection into a reservoir 3 Is a working fluid of (2);
2) At 1m 3 Displacement of/min 5m injection into reservoir 3 The mixture of the working solution and the steering agent is injected into the working solution, the weight of the steering agent is 1 percent of that of the working solution, and the particle size of the steering agent is 0.25-0.425mm; after the above mixture was injected into the reservoir, the pump pressure increased by 4.5MPa;
3) At 1.5m 3 Displacement of/min 30m injection into reservoir 3 A mixture of proppant of (a) and a working fluid; the propping agent is quartz sand, and the addition amount is 50kg/m 3 。
4) At 2m 3 Injection of 60m into the reservoir at a displacement of/min 3 Is composed of propping agent and working liquidPushing the mixture into the deep part of the reservoir to remove the deep pollution zone and dredge the fracture network.
Wherein, the working solution comprises the following components in parts by weight: a working fluid was obtained by mixing 100 parts of water, 0.001 part of drag reducer FR-800, 0.01 part of demulsifier FRZ-4 and 0.01 part of cleanup HSC-25.
The diverting agent is the diverting agent DCF-1 for the fracturing fluid, and when the temperature of the reservoir reaches about 90 ℃, the degradation rate of the DCF-1 can reach more than 95 percent.
Example 3
The embodiment provides a reservoir reconstruction method, wherein liquid injected into a reservoir is pumped, and the method specifically comprises the following steps:
1) At 0.2m 3 Displacement of/min 20m injection into reservoir 3 Is a working fluid of (2);
2) At 10m 3 Displacement per min 100m injection into a reservoir 3 The weight of the steering agent is 0.001 percent of the weight of the working solution, and the grain diameter of the steering agent is 0.25-0.425mm; after the above mixture was injected into the reservoir, the pump pressure increased by 4.5MPa;
3) At 0.2m 3 Displacement of/min 20m injection into reservoir 3 Is a working fluid of (2);
4) At 1.5m 3 Displacement of/min 8m injection into reservoir 3 The weight of the steering agent is 0.001 percent of the weight of the working solution, and the grain diameter of the steering agent is 0.25-0.425mm; when the above mixture is injected into the reservoir, the pump pressure rises by 1.2MPa;
5) At 0.2m 3 Displacement of/min 20m injection into reservoir 3 Is a working fluid of (2);
6) At 1m 3 Displacement of/min 5m injection into reservoir 3 The weight of the steering agent is 0.001 percent of the weight of the working solution, and the grain diameter of the steering agent is 0.25-0.425mm; after the above mixture was injected into the reservoir, the pump pressure increased by 0.8MPa;
7) At 15m 3 Displacement of/min 500m injection into a reservoir 3 A mixture of proppant of (a) and a working fluid; the propping agent isQuartz sand and haydite with the addition of 1000kg/m 3 。
8) At 2m 3 Injection of 50m into the reservoir at a displacement of/min 3 Pushing the mixture of the propping agent and the working fluid into the deep part of the reservoir to remove the deep pollution zone and dredge the formed fracture network.
Wherein, the working solution comprises the following components in parts by weight: 100 parts of water, 1 part of drag reducer FR-800, 2 parts of demulsifier FRZ-4 and 2 parts of cleanup additive HSC-25 are mixed to obtain a working fluid.
The steering agent is DCF-2, and when the reservoir temperature is about 90 ℃, the degradation rate of DCF-2 can reach more than 95 percent.
Example 4
The embodiment provides a reservoir reconstruction method, wherein liquid injected into a reservoir is pumped, and the method specifically comprises the following steps:
1) At 5m 3 Displacement per min 100m injection into a reservoir 3 Is a working fluid of (2);
2) At 5m 3 Displacement of/min 60m injection into reservoir 3 The weight of the steering agent is 0.5 percent of the weight of the working fluid, and the grain diameter of the steering agent is 0.25-0.425mm; when the above mixture was injected into the reservoir, the pump pressure increased by 3.9MPa;
3) At 5m 3 Displacement per min 100m injection into a reservoir 3 Is a working fluid of (2);
4) At 5m 3 Displacement of/min 60m injection into reservoir 3 The weight of the steering agent is 0.5 percent of the weight of the working fluid, and the grain diameter of the steering agent is 0.25-0.425mm; when the above mixture is injected into the reservoir, the pump pressure rises by 1.5MPa;
5) At 10m 3 Displacement of/min 300m injection into a reservoir 3 Is a gelled acid of (2);
6) At 3m 3 Injection of 50m into the reservoir at a displacement of/min 3 Pushing gelled acid into the deep part of the reservoir to remove the deep pollution zone and dredging the formed fracture network.
Wherein, the working solution comprises the following components in parts by weight: a working fluid was obtained by mixing 100 parts of water, 0.1 part of drag reducer FR-800,0.5 part of demulsifier FRZ-4 and 0.5 part of cleanup HSC-25.
The steering agent is SR-3, and when the reservoir temperature is about 90 ℃, the degradation degree of SR-3 can reach more than 95%.
The preparation method of the gelled acid comprises the following steps of: 100 parts of hydrochloric acid, 0.8 part of gelling agent KMS-50, 2 parts of corrosion inhibitor KMS-6, 0.8 part of demulsifier FRZ-4, 1 part of iron ion stabilizer KMS-7 and 0.8 part of cleanup additive HSC-25 are mixed to obtain gelled acid.
Example 5
The embodiment provides a reservoir reconstruction method, wherein liquid injected into a reservoir is pumped, and the method specifically comprises the following steps:
1) At 2.2m 3 Displacement per min 100m injection into a reservoir 3 Is a working fluid of (2);
2) At 2.5m 3 Displacement of/min 60m injection into reservoir 3 The weight of the steering agent is 0.5 percent of the weight of the working fluid, and the grain diameter of the steering agent is 0.25-0.425mm; after the above mixture was injected into the reservoir, the pump pressure increased by 4.1MPa;
3) At 10m 3 Displacement of/min 300m injection into a reservoir 3 Is a ground crosslinking acid of (2);
4) At 3m 3 Injection of 50m into the reservoir at a displacement of/min 3 The ground cross-linking acid is pushed into the deep part of the reservoir to remove the deep part of the pollution zone, and the formed fracture network is dredged.
Wherein, the working solution comprises the following components in parts by weight: 100 parts of water, 0.1 part of drag reducer FR-800,0.5 parts of demulsifier FRZ-4 and 0.5 part of cleanup additive HSC-25 are mixed to obtain a working fluid.
The steering agent is SR-3, and when the reservoir temperature is about 90 ℃, the degradation rate of SR-3 can reach more than 95%.
The ground crosslinking acid comprises the following components in percentage by weight: 20% hydrochloric acid, 0.8% thickening agent KMS-30A, 1% demulsifier FRZ-4, 1% cleanup additive HSC-25, 2% corrosion inhibitor KMS-6, 1% iron ion stabilizer KMS-7, 0.5% regulator KMS-30C, 0.8% cross-linking agent KMS-30B and 68.4% water are mixed to obtain the ground gelled acid.
Example 6
The embodiment provides a reservoir reconstruction method, wherein liquid injected into a reservoir is pumped, and the method specifically comprises the following steps:
1) At 2m 3 Displacement of/min 45m injection into reservoir 3 Is a working fluid of (2);
2) At 1.8m 3 Displacement of/min 40m injection into reservoir 3 The weight of the steering agent is 0.5 percent of the weight of the working fluid, and the grain diameter of the steering agent is 0.25-0.425mm; after the above mixture was injected into the reservoir, the pump pressure increased by 4.5MPa;
3) At 5m 3 Displacement of/min 60m injection into reservoir 3 Is a working fluid of (2);
4) At 5m 3 Displacement of/min 60m injection into reservoir 3 The mixture of the working solution and the steering agent is 0.5 percent of the weight of the injected steering agent based on the weight of the working solution, and the particle size of the steering agent is 0.25-0.425mm; when the above mixture is injected into the reservoir, the pump pressure rises by 1.5MPa;
5) At 10m 3 Displacement of/min 300m injection into a reservoir 3 Is turned to the acid by the cleaning of (a);
6) At 2m 3 Injection of 50m into the reservoir at a displacement of/min 3 Pushing the cleaning diverting acid into the deep part of the reservoir to remove the deep pollution zone and dredging the formed fracture network.
Wherein, the working solution comprises the following components in parts by weight: a working fluid was obtained by mixing 100 parts of water, 0.1 part of drag reducer FR-800,0.5 part of demulsifier FRZ-4 and 0.5 part of cleanup HSC-25.
The steering agent is SR-3, and when the reservoir temperature is about 90 ℃, the degradation rate of SR-3 can reach more than 95%.
The components of the cleaning diverting acid are calculated in weight percent, and the preparation steps comprise: 20% HCl, 10% diverting acid main agent DCA-1, 0.2% resistance-reducing agent KMS-50, 2% corrosion inhibitor DCA-6 and 67.8% water are mixed to obtain the clean diverting acid.
Example 7
The embodiment provides a reservoir reconstruction method, wherein liquid injected into a reservoir is pumped, and the method specifically comprises the following steps:
1) At 5m 3 A displacement of/min injects 80m into the reservoir 3 Is a working fluid of (2);
2) At 5m 3 A displacement of/min injects 80m into the reservoir 3 The weight of the steering agent is 0.5 percent of the weight of the working fluid, and the grain diameter of the steering agent is 0.25-0.425mm; when the above mixture was injected into the reservoir, the pump pressure increased by 6.1MPa;
3) At 8m 3 Displacement per min 100m injection into a reservoir 3 Is a temperature-controlled acid;
4) At 2.5m 3 Injection of 50m into the reservoir at a displacement of/min 3 The temperature-controlled variable viscous acid is pushed into the deep part of the reservoir to remove the deep part pollution zone, and the formed fracture network is dredged.
Wherein, the working solution comprises the following components in parts by weight: a working fluid was obtained by mixing 100 parts of water, 0.1 part of drag reducer FR-800,0.5 part of demulsifier FRZ-4 and 0.5 part of cleanup HSC-25.
The steering agent is DCF-1, and when the reservoir temperature is about 90 ℃, the degradation rate of DCF-1 can reach more than 95 percent.
The temperature-controlled variable-viscosity acid comprises the following components in percentage by weight: the temperature-controlled variable mucic acid is obtained by mixing 20% HCl, 0.8% gelling agent KMS-50, 4% corrosion inhibitor KMS-6, 2% cleanup additive HSC-25, 2% demulsifier FRZ-4, 2% iron ion stabilizer KMS-7, 0.7% activator KMS-50H and 68.5% water.
Example 8
The embodiment provides a reservoir reconstruction method, wherein liquid injected into a reservoir is pumped, and the method specifically comprises the following steps:
1) At 5m 3 A displacement of/min injects 80m into the reservoir 3 Is a working fluid of (2);
2) At 5m 3 A displacement of/min injects 80m into the reservoir 3 The weight of the steering agent is 0.5 percent of the weight of the working fluid, and the grain diameter of the steering agent is 0.25-0.425mm; when the above mixture was injected into the reservoir, the pump pressure increased by 6.1MPa;
3) At 5m 3 A displacement of/min injects 80m into the reservoir 3 Is a working fluid of (2);
4) At 5m 3 A displacement of/min injects 80m into the reservoir 3 The weight of the steering agent is 0.5 percent of the weight of the working fluid, and the grain diameter of the steering agent is 0.25-0.425mm; when the above mixture is injected into the reservoir, the pump pressure rises by 4.3MPa;
5) At 8m 3 Displacement per min 100m injection into a reservoir 3 Is a temperature-controlled acid;
6) At 2.5m 3 Injection of 50m into the reservoir at a displacement of/min 3 The temperature-controlled variable viscous acid is pushed into the deep part of the reservoir to remove the deep part pollution zone, and the formed fracture network is dredged.
Wherein, the working solution comprises the following components in parts by weight: a working fluid was obtained by mixing 100 parts of water, 0.1 part of drag reducer FR-800,0.5 part of demulsifier FRZ-4 and 0.5 part of cleanup HSC-25.
The steering agent is DCF-1, and when the reservoir temperature is about 90 ℃, the degradation rate of DCF-1 can reach more than 95 percent.
The temperature-controlled variable-viscosity acid comprises the following components in percentage by weight: the temperature-controlled variable mucic acid is obtained by mixing 20% HCl, 0.8% gelling agent KMS-50, 4% corrosion inhibitor KMS-6, 2% cleanup additive HSC-25, 2% demulsifier FRZ-4, 2% iron ion stabilizer KMS-7, 0.7% activator KMS-50H and 68.5% water.
For examples 1-3, the production of natural gas before and after reservoir rebuild (rebuild time 15min-300 min) was measured by a natural gas production process conventional in the art, and the results are shown in table 1.
For examples 4-8, the oil production before and after reservoir intervention was measured by a conventional oil recovery process in the art, and the results are shown in table 1.
TABLE 1
The test results of examples 1-8 in table 1 show that the reservoir reconstruction method provided by the invention can obviously improve the oil and gas exploitation yield after the unconventional oil and gas resource reservoir is reconstructed.
Finally, it should be noted that: the above embodiments are only for illustrating the technical solution of the present invention, and not for limiting the same; although the invention has been described in detail with reference to the foregoing embodiments, it will be understood by those of ordinary skill in the art that: the technical scheme described in the foregoing embodiments can be modified or some or all of the technical features thereof can be replaced by equivalents; such modifications and substitutions do not depart from the spirit of the invention.

Claims (1)

1. A method of reservoir reformation comprising the steps of:
1) At 0.2-15m 3 The displacement of/min is injected into the reservoir for 20-300m 3 Is a working fluid of (2);
2) At 1-10m 3 The displacement per min is 5-100m into the reservoir 3 The weight ratio of the working fluid to the steering agent is (100.021-100.5): (0.001-1), and the particle size of the steering agent is 0.25-0.425mm;
3) At 1.5-15m 3 The displacement per min is injected into the reservoir for 30-500m 3 A mixture of a working fluid and a proppant or an acid fluid;
4) Reinjecting the working solution for displacement;
repeating steps 1) -2) before step 3) is performed;
the working solution comprises the following components in parts by weight: 100 parts of water, 0.001-1 part of drag reducer, 0.01-2 parts of demulsifier and 0.01-2 parts of cleanup additive, wherein the demulsifier is selected from nonionic surfactantAnd one or both of a cationic surfactant, the cleanup additive being selected from fluorosurfactants; the steering agent is a degradable steering agent, and the degradable steering agent is at least one selected from fibers, modified fibers, polyester particles and crosslinked polymer particles; the propping agent is selected from one or two of quartz sand and ceramsite, and the adding amount of the propping agent is 50-1000kg/m based on the volume of the working solution 3 ；
When the reservoir is a tight sandstone reservoir, the acid solution is selected from organic earth acids; the organic earth acid comprises the following components in parts by weight: 100 parts of mixed acid liquor, 1-4 parts of viscosity stabilizer, 2-7 parts of corrosion inhibitor, 1-4 parts of cleanup additive, 1-4 parts of iron ion stabilizer, 1-4 parts of demulsifier, 0.2-0.4 part of gelling agent and 3-6 parts of methanol; wherein the mixed acid solution comprises hydrochloric acid, acetic acid and water;
when the reservoir is a tight carbonate reservoir, the acid liquor is selected from gelled acid, ground cross-linking acid, clean diverting acid or temperature-controlled variable viscosity acid; the gelled acid comprises the following components in parts by weight: 100 parts of hydrochloric acid, 0.3-1 part of gelatinizer, 1-4 parts of corrosion inhibitor, 0.5-1 part of demulsifier, 0.5-2 parts of iron ion stabilizer and 0.5-1 part of cleanup additive; the ground crosslinking acid comprises the following components in percentage by weight: 15-25% of hydrochloric acid, 0.5-1% of thickening agent, 0.5-5% of demulsifier, 0.5-5% of cleanup additive, 1-5% of corrosion inhibitor, 0.5-5% of iron ion stabilizer, 0.5-5% of regulator, 0.5-1% of cross-linking agent and the balance of water; the cleaning diverting acid comprises the following components in percentage by weight: 15-25% of hydrochloric acid, 5-15% of steering acid main agent, 0.1-1% of resistance reducing agent, 1-5% of corrosion inhibitor and the balance of water; the temperature-control variable viscosity acid comprises the following components in percentage by weight: 20% hydrochloric acid, 0.6-1.2% gelatinizer, 1-6% corrosion inhibitor, 1-4% cleanup additive, 1-4% demulsifier, 1-4% iron ion stabilizer, 0.5-0.8% activator and the balance water.
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