阅读说明：本技术 一种适合于挥发性油藏的储层改造增产方法 (Reservoir transformation yield increasing method suitable for volatile oil reservoir ) 是由 张炜 刘炜 李奎东 黄晓凯 徐苗 陈建达 华继军 王龙卫 于 2020-12-09 设计创作，主要内容包括：本发明公开了一种适合于挥发性油藏的储层改造增产方法,包括水力加砂压裂与酸压施工步骤,具体包括如下步骤：注入酸液预处理近井地带,降低施工压力；注入滑溜水,降低储层温度,沟通天然裂缝；注入滑溜水压裂液携带小粒径支撑剂,促进缝长延伸,沟通微裂缝,提高远井供给半径；注入降阻酸酸液,利用降阻酸酸液的刻蚀作用,形成不规则蚓孔,提高中场裂缝导流能力；注入线性胶压裂液携带大粒径支撑剂,以提高近井地带导流能力,利于油的流动能力；顶替滑溜水后,停止泵注。本发明可以形成稳定的高导流通道,改善压降剖面,能大幅提升单位压降产油气量,适用于类似挥发性油藏储层的高效改造。(The invention discloses a reservoir transformation production increasing method suitable for a volatile oil reservoir, which comprises the steps of hydraulic sand fracturing and acid fracturing construction, and specifically comprises the following steps: injecting acid liquor to pretreat the near-well zone, and reducing the construction pressure; injecting slick water, reducing the temperature of a reservoir and communicating natural fractures; injecting slickwater fracturing fluid to carry small-particle-size propping agent, promoting the extension of the joint length, communicating micro-cracks and improving the far well supply radius; injecting a resistance reducing acid solution, and forming irregular earthworm holes by using the etching effect of the resistance reducing acid solution, so that the flow conductivity of the median fissure is improved; injecting the linear gel fracturing fluid to carry a large-particle-size proppant so as to improve the flow conductivity of a near wellbore zone and facilitate the flow capacity of oil; and stopping pumping after the slippery water is replaced. The invention can form a stable high-flow-guide channel, improve the pressure drop profile, greatly improve the unit pressure drop oil and gas production rate, and is suitable for the high-efficiency transformation of similar volatile oil reservoir reservoirs.)

1. A reservoir transformation production increasing method suitable for a volatile oil reservoir is characterized by comprising the steps of hydraulic sand fracturing and acid fracturing construction, and specifically comprises the following steps:

s1, injecting acid liquor to pretreat the near-well zone, and reducing the construction pressure;

s2, injecting slick water, reducing the temperature of the reservoir and communicating natural fractures;

s3, injecting slickwater fracturing fluid to carry small-particle-size propping agent, promoting the extension of the joint length, communicating micro cracks and improving the supply radius of a far well;

s4, injecting a resistance reducing acid solution, and forming irregular earthworm holes by using the etching effect of the resistance reducing acid solution to improve the flow conductivity of the median fissure;

s5, injecting linear gel fracturing fluid to carry a large-particle-size propping agent so as to improve the flow conductivity of a near wellbore zone and facilitate the flowing capacity of oil;

and S6, stopping pumping after the slick water is replaced.

2. A reservoir modification stimulation method suitable for volatile oil reservoirs according to claim 1, further comprising a step S0 of optimizing the number of perforation clusters and the interval between segment clusters before construction, specifically:

s01, collecting data such as reservoir physical properties and logging data;

s02, comprehensively considering parameters such as natural fracture direction and intersection relation, a regional stress field, rock physical properties and the like, establishing a complex phase state flow model of the multi-scale fracture, wherein the established model comprises a far well water-reducing water-making long fracture area, a middle acid liquid etching strengthening seepage area and a near well proppant filling area, simulating and calculating stress values and stress field changes under different fracture spacing conditions through the complex phase state flow model of the multi-scale fracture, and performing parameter and model fitting according to actual pumping on the site of a constructed well;

s03, simulating and calculating parameters such as stress values, stress field changes, induced stress differences and the like under different fracture intervals through Intech software according to the horizontal pressure difference of the region where the horizontal well is located;

and S04, optimizing the number of perforating clusters and the interval between the segment clusters according to the calculation result in the step S4 by combining the phase state change rule of the oil reservoir seepage interval.

3. A reservoir modification stimulation method suitable for volatile oil reservoirs according to claim 2, wherein the data collected in the step S01 comprises sonic moveout, density, natural potential, natural gamma log, reservoir elastic modulus, horizontal geostress X, horizontal geostress Y, reservoir rock poisson' S ratio, reservoir original pore pressure, reservoir thickness, regional geostress prediction results.

4. A reservoir modification stimulation method suitable for volatile oil reservoirs according to claim 1 or 2, wherein in step S02, a complex phase-state flow model of multi-scale fractures is established by means of the Fracman software by means of Mote Carlo random fracture simulation, risk simulation, finite element Mesh use, post-processing output and the like.

5. A reservoir modification stimulation method suitable for volatile oil reservoirs according to claim 1 or 2, wherein in step S04, the number of perforation clusters is designed so that natural fractures can be opened by induced stress difference, and the interval between segment clusters is designed so that induced pressure difference between segments is larger than horizontal pressure difference.

6. Reservoir modification stimulation method suitable for volatile oil reservoirs according to claim 1 or 2, characterized in that in step S1, the displacement is 0.5-4m³Injecting 10-40 m/min³Pretreating the stratum with acid liquor; the acid solution comprises, by mass, 15-20% of hydrochloric acid, 1-2% of a corrosion inhibitor, 1-2% of an iron ion stabilizer, 1-2% of a clay stabilizer, 1-2% of a cleanup additive, and the balance of water.

7. Reservoir modification stimulation method suitable for volatile oil reservoirs according to claim 1 or 2, characterized in that in step S2, the displacement is 6-12m³Injecting slick water 40-150 m/min³The slickwater is 0.04 to 0.1 percent by massResistance agent, 0.3-1% of emulsion breaker, 0.2-0.5% of anti-swelling agent, and the balance of water.

8. Reservoir modification stimulation method suitable for volatile oil reservoirs, according to claim 1 or 2, characterized in that in step S3, the displacement is 12-14m³Min, 600-800m³Injecting a sand carrying liquid into the slickwater, wherein the sand types are 70-140 meshes of quartz sand and 70-140 meshes of low-density ceramsite, and the sand ratio is 3-10%; wherein the slickwater comprises, by mass percent, 0.04-0.1% of resistance reducing agent, 0.3-1% of emulsion breaking preventing agent, 0.2-0.5% of anti-swelling agent, and the balance of water.

9. Reservoir modification stimulation method suitable for volatile oil reservoirs according to claim 1 or 2, characterized in that in step S4, the displacement is 12-14m³200 + 600 m/min injection³Reducing resistance acid liquor; wherein the resistance reducing acid is composed of 15-20% hydrochloric acid, 0.06-0.1% acid liquid resistance reducing agent, 1-2% corrosion inhibitor, 0.5-1% phase permeation improver, and the balance of water.

10. Reservoir modification stimulation method suitable for volatile oil reservoirs, according to claim 1 or 2, characterized in that in step S5, the displacement is 14-16m³Min, using 80-100m³Injecting the linear gel fracturing fluid into a sand carrying fluid, wherein the sand types are 40/70-mesh low-density ceramsite, 30/50-mesh low-density ceramsite and 20/40-mesh low-density ceramsite; the sand ratio is 10-14% respectively; 14-16%; 10-16%; wherein the linear gel fracturing fluid consists of 0.2 to 0.3 percent of thickening agent, 0.2 to 0.3 percent of cross-linking agent, 0.5 to 1 percent of emulsion breaker, 0.2 to 0.5 percent of synergist, 0.05 to 0.1 percent of gel breaker and the balance of water.

Technical Field

The invention relates to the field of petroleum and natural gas engineering, in particular to a reservoir transformation yield-increasing method suitable for volatile oil reservoirs.

Background

Aiming at volatile oil reservoirs, similar oil fields at home and abroad mainly adopt two development modes of gas injection and water injection at present. The gas injection displaces the crude oil in the reservoir to the production well and maintains some or all of the formation pressure, preventing the crude oil from shrinking. But the investment is too large and the injection pressure is high by adopting the gas injection mode. Water injection exploitation is also widely adopted, because the volatile oil has low viscosity and is easy to cause water invasion, the yield of an oil-gas well is reduced rapidly, and a reservoir transformation yield-increasing method for volatile oil reservoirs is not reported in related published patents at present.

Disclosure of Invention

The invention aims to solve the technical problem of providing a reservoir transformation production increasing method which can increase the pressure drop oil yield and is suitable for volatile oil reservoirs aiming at the defects in the prior art.

The technical scheme adopted by the invention is as follows: a reservoir transformation production increasing method suitable for a volatile oil reservoir is characterized by comprising the steps of hydraulic sand fracturing and acid fracturing construction, and specifically comprises the following steps:

s1, injecting acid liquor to pretreat the near-well zone, reducing construction pressure and removing near-well pollution;

s2, injecting slickwater fracturing fluid, and fully communicating natural fractures by utilizing high filtration loss efficiency of slickwater while simultaneously communicating natural fractures

Reducing the reservoir temperature;

s3, injecting slickwater fracturing fluid to carry small-particle-size propping agent, promoting the extension of the joint length, fully communicating and filling the microcracks, and improving the contact area and the supply radius of the far well;

s4, injecting a resistance reducing acid solution, and forming irregular earthworm holes by utilizing the non-uniform etching effect of the resistance reducing acid solution, so that the flow conductivity of the middle zone cracks is improved, and the pressure loss is reduced;

s5, injecting a linear gel fracturing fluid to carry a large-particle-size propping agent, reducing the skin coefficient, establishing a high-flow-guiding channel and improving the flow capacity of oil;

and S6, stopping pumping after the slick water is replaced.

According to the technical scheme, the method further comprises a step S0 of optimizing the number of perforating clusters and the interval between the segment clusters before construction, and specifically comprises the following steps:

s01, collecting data such as reservoir physical properties and logging data;

s02, comprehensively considering parameters such as natural fracture direction and intersection relation, a regional stress field, rock physical properties and the like, establishing a complex phase state flow model of the multi-scale fracture, wherein the established model comprises a far well water-reducing water-making long fracture area, a middle acid liquid etching strengthening seepage area and a near well proppant filling area, simulating and calculating stress values and stress field changes under different fracture spacing conditions through the complex phase state flow model of the multi-scale fracture, and performing parameter and model fitting according to actual pumping on the site of a constructed well;

s03, simulating and calculating parameters such as stress values, stress field changes, induced stress differences and the like under different fracture intervals through Intech software according to the horizontal pressure difference of the region where the horizontal well is located;

and S04, optimizing the number of perforating clusters and the interval between the segment clusters according to the calculation result in the step S4 by combining the phase state change rule of the oil reservoir seepage interval.

According to the above technical solution, the data collected in step S01 includes acoustic moveout, density, natural potential, natural gamma log, reservoir elastic modulus, horizontal ground stress X, horizontal ground stress Y, reservoir rock poisson' S ratio, reservoir original pore pressure, reservoir thickness, regional ground stress, and the like.

According to the technical scheme, in step S02, Fracman software is used, and methods such as Mote Carlo random crack simulation, risk simulation, finite element Mesh use, post-processing output and the like are adopted to establish a multi-scale crack complex phase state flow model.

According to the technical scheme, in the step S04, the number of the perforation clusters is designed to meet the condition that the natural cracks can be opened by induced stress difference, and the interval between the segment clusters is designed to meet the condition that the induced pressure difference between the segments is larger than the horizontal pressure difference.

According to the technical scheme, in the step S1, the displacement is 0.5-4m³Injecting 10-40 m/min³Pretreating the stratum with acid liquor; the acid solution comprises, by mass, 15-20% of hydrochloric acid (the concentration of the hydrochloric acid is 20% -31%), 1-2% of a corrosion inhibitor, 1-2% of an iron ion stabilizer, 1-2% of a clay stabilizer, 1-2% of a cleanup additive, and the balance of water. Wherein, the hydrochloric acid, the corrosion inhibitor, the iron ion stabilizer, the clay stabilizer and the cleanup additive are all commercial products.

According to the technical scheme, in the step S2, the displacement is 6-12m³Injecting slick water 40-150 m/min³The slickwater comprises, by mass, 0.04-0.1% of a drag reducer, 0.3-1% of an anti-emulsion breaker, 0.2-0.5% of an anti-swelling agent, and the balance of water. Wherein the drag reducer and the anti-swelling agent are commercially available products, and the emulsion breaker is complex of alkylphenol polyoxyethylene sodium sulfate, amino trimethylene phosphonic acid and diethylene glycol ethyl etherThe water solution of the preparation comprises the components in a mass ratio of 1-3: 3-1: 1-2, and the total concentration is 30-80%, preferably 50-60%.

According to the technical scheme, in the step S3, the displacement is 12-14m³Min, 600-800m³Injecting a sand carrying liquid into the slickwater, wherein the sand type is 70-140 meshes of quartz sand or 70-140 meshes of low-density ceramsite, and the sand ratio is 3-10%; wherein the slickwater comprises, by mass percent, 0.04-0.1% of resistance reducing agent, 0.3-1% of emulsion breaking preventing agent, 0.2-0.5% of anti-swelling agent, and the balance of water. Wherein the drag reducer and the anti-swelling agent are commercially available products, the emulsion breaker is an aqueous solution of a compound of alkylphenol polyoxyethylene sodium sulfate, aminotrimethylene phosphonic acid and diethylene glycol ethyl ether, the ratio of the components is 1-3: 3-1: 1-2, and the total concentration is 30-80%, preferably 50-60%.

According to the technical scheme, in the step S4, the displacement is 12-14m³200 + 600 m/min injection³Reducing resistance acid liquor; wherein the resistance-reducing acid consists of 15-20% of hydrochloric acid (the concentration of the hydrochloric acid is 20% -31%), 0.06-0.1% of acid liquid resistance-reducing agent, 1% -2% of corrosion inhibitor, 0.5% -1% of phase permeation improver and the balance of water. The hydrochloric acid and the corrosion inhibitor are commercial products, the acid liquor resistance reducing agent is a compound of polyvinylpyrrolidone and polydiallyldimethylammonium chloride, the average molecular weight of the polyvinylpyrrolidone is 70-100 ten thousand, the average molecular weight of the polydiallyldimethylammonium chloride is 45-60 ten thousand, the ratio of the polyvinylpyrrolidone to the polydiallyldimethylammonium chloride is 7-8: 3-2, the phase permeation improver is an aqueous solution of a compound of polyoxyethylene ether, flutolanil and sodium carbonate, the ratio of the components is 2-4: 2-1: 3-1, and the total concentration is 40-90%, preferably 50-90%.

According to the technical scheme, in the step S5, the displacement is 14-16m³Min, using 80-100m³Injecting the linear gel fracturing fluid into a sand carrying fluid, wherein the sand types are 40/70-mesh low-density ceramsite, 30/50-mesh low-density ceramsite and 20/40-mesh low-density ceramsite; the sand ratio is 10-14% respectively; 14-16%; 10-16%; wherein the linear gel fracturing fluid consists of 0.2 to 0.3 percent of thickening agent, 0.2 to 0.3 percent of cross-linking agent, 0.5 to 1 percent of emulsion breaker, 0.2 to 0.5 percent of seepage and absorption oil displacement agent, 0.05 to 0.1 percent of gel breaker and the balance of water. Wherein the content of the first and second substances,the thickening agent, the cross-linking agent and the gel breaker are commercially available products, the emulsion breaker is an aqueous solution of a compound of alkylphenol polyoxyethylene sodium sulfate, aminotrimethylene phosphonic acid and diethylene glycol ethyl ether, the ratio of the components is 1-3: 3-1: 1-2, and the total concentration is 30-80%, preferably 50-60%; the imbibition oil displacement agent is an aqueous solution of a compound of fatty alcohol polyoxyethylene ether carboxylate, polyoxyethylene oleate and ethylene glycol monobutyl ether, the proportion of each component is 2-3: 3-2: 1-2, and the total concentration is 50-80%, preferably 60-70%.

The beneficial effects obtained by the invention are as follows:

the invention provides a reservoir stratum modification yield increasing method for increasing oil and gas production by pressure drop aiming at the modification requirement of volatile oil reservoirs. The method gives full play to the advantages of the targeted processes of different phase regions, adopts the preposed acid liquor to pretreat the near-wellbore area, reduces the construction pressure and removes the near-wellbore pollution; then injecting slickwater fracturing fluid, fully communicating natural fractures by utilizing high filtration loss efficiency of slickwater, and simultaneously reducing the temperature of a reservoir stratum; then injecting slickwater fracturing fluid to carry a small-particle-size propping agent, promoting the extension of the joint length, fully communicating and filling the micro-cracks, improving the contact area and the supply radius of a far well, and simultaneously, an emulsion-preventing demulsifier can effectively neutralize the charges of an oil-water interface, prevent the emulsification of oil and water and reduce the damage of a reservoir stratum; injecting resistance-reducing acid liquor, wherein the acid liquor resistance reducing agent can reduce the construction friction resistance of an acid liquor system, is beneficial to large-displacement construction, promotes the non-uniform etching effect of the resistance-reducing acid liquor, forms irregular earthworm holes, can increase the wetting contact angle between an oil phase and rock by using a phase seepage improver, reduces the adhesion of the oil phase on the surface of the rock, improves the flow conductivity of a middle-zone crack, improves the seepage capability of an artificial crack, increases the reservoir transformation volume and reduces the pressure loss; and finally, injecting a linear gel fracturing fluid to carry a large-particle-size propping agent, and meanwhile, permeating and absorbing an oil displacement agent to improve the surface charge density of the rock, increase the electrostatic repulsion between the oil phase and the rock surface, reduce the near-well skin coefficient, establish a stable high-flow-guide channel, improve a pressure drop profile, greatly improve the unit pressure drop oil and gas yield, and be suitable for the efficient transformation of similar volatile oil reservoir reservoirs.

Detailed Description

The present invention is further described below.

The present invention will be further described with reference to the following examples. The well A is a typical volatile oil reservoir well, the well depth is 3850m, the vertical depth is 2650m, the gas testing section is 608m long, and the reservoir reconstruction method is divided into 7 sections, wherein the reservoir reconstruction method comprises the following steps:

(1) collecting data such as physical properties and logging data of the reservoir, including acoustic time difference, density, natural potential, natural gamma logging curve, elastic modulus of the reservoir, horizontal ground stress X, horizontal ground stress Y, Poisson's ratio of reservoir rock, original pore pressure of the reservoir, thickness of the reservoir, regional ground stress and the like;

(2) comprehensively considering parameters such as natural crack directions, intersection relations, regional stress fields, rock physical properties and the like, establishing a complex phase state flow model of the multi-scale crack by using Fracman software and adopting methods such as Mote Carlo random crack simulation, risk simulation, finite element Mesh use, post-processing output and the like, wherein the established model comprises a far well water-reducing water-making long crack area, a middle acid liquid etching strengthening seepage area and a near well proppant filling area, simulating and calculating stress values and stress field changes under different crack spacing conditions through Intech software, and performing pumping for parameter and model fitting optimization;

(3) pump injection program design, combining the phase state change rule of the oil reservoir seepage interval, and optimizing pump injection parameters according to the data in the step (2);

(4) the field construction process flow comprises the following steps: at a displacement of 0.5m³Min injection 10m³Pretreating the stratum with acid liquor; the acid solution comprises, by mass, 15% of hydrochloric acid (the concentration of the hydrochloric acid is 20%), 1% of a corrosion inhibitor, 1% of an iron ion stabilizer, 1% of a clay stabilizer and 1% of a cleanup additive, and the balance of water. Wherein, the hydrochloric acid, the corrosion inhibitor, the iron ion stabilizer, the clay stabilizer and the cleanup additive are all commercial products.

(5) At a discharge capacity of 6m³Permin injection of slickwater 40m³(ii) a The slickwater comprises, by mass, 0.04% of resistance reducing agent, 0.3% of emulsion breaking preventing agent and 0.2% of anti-swelling agent, and the balance of water. Wherein the drag reducer and the anti-swelling agent are commercially available products, and the emulsion breaker is alkylphenol polymerThe water solution of the compound of the oxyethylene sodium sulfate, the amino trimethylene phosphonic acid and the diethylene glycol ethyl ether comprises the components in a mass ratio of 1:3:1, and the total concentration is 50%.

(6) At a discharge capacity of 12m³Min, using 600m³Injecting a sand carrying liquid into the slickwater, wherein the sand type is 70-140 meshes of quartz sand, and the sand ratio is 3-10%; the slickwater comprises, by mass, 0.04% of resistance reducing agent, 0.3% of emulsion breaking preventing agent and 0.2% of anti-swelling agent, and the balance of water. Wherein the drag reducer and the anti-swelling agent are commercially available products, the emulsion breaker is an aqueous solution of a compound of alkylphenol polyoxyethylene sodium sulfate, aminotrimethylene phosphonic acid and diethylene glycol ethyl ether, the ratio of the components is 3:1:2, and the total concentration is 60%.

(7) At a discharge capacity of 12m³Min injection 600m³Reducing the resistance of the acid; wherein the resistance reducing acid consists of 15 percent hydrochloric acid (the concentration of the hydrochloric acid is 20 percent), 0.06 percent acid liquid resistance reducing agent, 1 percent corrosion inhibitor, 0.5 percent phase permeation improver and the balance of water. The acid liquor resistance reducing agent is a compound of polyvinylpyrrolidone and polydiallyldimethylammonium chloride, wherein the average molecular weight of the polyvinylpyrrolidone is 70 ten thousand, the average molecular weight of the polydiallyldimethylammonium chloride is 45 ten thousand, the ratio of the polyvinylpyrrolidone to the polydiallyldimethylammonium chloride is 7:3, the phase permeation improver is an aqueous solution of a compound of polyoxyethylene ether, flutolanil and sodium carbonate, the ratio of the components is 2:2:3, and the total concentration is 70%.

(8) At a displacement of 14m³Min, 80m³Injecting the linear gel fracturing fluid into a sand carrying fluid, wherein the sand types are 40/70-mesh low-density ceramsite, 30/50-mesh low-density ceramsite and 20/40-mesh low-density ceramsite; the sand ratios are respectively 10%; 14 percent; 10 percent; the linear gel fracturing fluid consists of 0.2 percent of thickening agent, 0.2 percent of cross-linking agent, 0.5 percent of emulsion breaker, 0.2 percent of seepage and absorption oil displacement agent, 0.05 percent of gel breaker and the balance of water. Wherein the thickening agent, the cross-linking agent and the gel breaker are commercially available products, the emulsion breaker is an aqueous solution of a compound of alkylphenol polyoxyethylene sodium sulfate, aminotrimethylene phosphonic acid and diethylene glycol ethyl ether, the ratio of the components is 1:3:1, and the total concentration is 50%; the imbibition oil displacement agent is fatty alcohol polyoxyethylene ether carboxylate, oleic acid polyoxyethylene ester and ethylene glycol monobutyl ether complexThe water solution of the ingredients has the ratio of 2:3:1, and the total concentration is 60%.

(9) Displacing 100m³And stopping pumping after water is slipped.

Example 2:

the well B is a volatile oil reservoir well with a well depth of 3628m and a vertical depth of 2400m, and the reservoir transformation method at one section comprises the following steps:

(1) collecting data such as physical properties and logging data of the reservoir, including acoustic time difference, density, natural potential, natural gamma logging curve, elastic modulus of the reservoir, horizontal ground stress X, horizontal ground stress Y, Poisson's ratio of reservoir rock, original pore pressure of the reservoir, thickness of the reservoir, regional ground stress and the like;

(2) comprehensively considering parameters such as natural crack directions, intersection relations, regional stress fields, rock physical properties and the like, establishing a complex phase state flow model of the multi-scale crack by using Fracman software and adopting methods such as Mote Carlo random crack simulation, risk simulation, finite element Mesh use, post-processing output and the like, wherein the established model comprises a far well water-reducing water-making long crack area, a middle acid liquid etching strengthening seepage area and a near well proppant filling area, simulating and calculating stress values and stress field changes under different crack spacing conditions through Intech software, and performing pumping for parameter and model fitting optimization;

(3) pump injection program design, combining the phase state change rule of the oil reservoir seepage interval, and optimizing pump injection parameters according to the data in the step (2);

(4) the field construction process flow comprises the following steps: at a displacement of 4m³Min injection 40m³Pretreating the stratum with acid liquor; the acid solution comprises, by mass, 20% of hydrochloric acid (the concentration of the hydrochloric acid is 31%), 2% of a corrosion inhibitor, 2% of an iron ion stabilizer, 2% of a clay stabilizer and 2% of a cleanup additive, and the balance of water.

(5) At a discharge capacity of 12m³Permin injection of slickwater 150m³(ii) a The slickwater comprises, by mass, 0.1% of a drag reducer, 1% of an anti-emulsion splitter and 0.5% of an anti-swelling agent, and the balance of water. Wherein the emulsion breaker is a compound of alkylphenol polyoxyethylene sodium sulfate, aminotrimethylene phosphonic acid and diethylene glycol ethyl etherThe water solution comprises the components in a mass ratio of 3:1:2, and the total concentration is 60%.

(6) At a displacement of 14m³Min, 800m³Injecting a sand-carrying liquid into the slickwater, wherein the sand type is 70-140 meshes of low-density ceramsite, and the sand ratio is 3-10%; the slickwater comprises, by mass, 0.1% of a drag reducer, 1% of an anti-emulsion splitter and 0.5% of an anti-swelling agent, and the balance of water. Wherein the emulsion breaker is an aqueous solution of a compound of alkylphenol polyoxyethylene sodium sulfate, aminotrimethylene phosphonic acid and diethylene glycol ethyl ether, the ratio of the components is 3:1:2, and the total concentration is 60%.

(7) At a displacement of 14m³Permin injection 200m³Reducing the resistance of the acid; wherein the resistance reducing acid consists of 20 percent of hydrochloric acid (the concentration of the hydrochloric acid is 31 percent), 0.1 percent of acid liquid resistance reducing agent, 2 percent of corrosion inhibitor and 1 percent of phase permeation improver, and the balance of water. The acid liquor resistance reducing agent is a compound of polyvinylpyrrolidone and polydiallyldimethylammonium chloride, wherein the average molecular weight of the polyvinylpyrrolidone is 100 ten thousand, the average molecular weight of the polydiallyldimethylammonium chloride is 60 ten thousand, the ratio of the polyvinylpyrrolidone to the polydiallyldimethylammonium chloride is 8:2, the phase permeation improver is an aqueous solution of a compound of polyoxyethylene ether, flutolanil and sodium carbonate, the ratio of the components is 4:1:1, and the total concentration is 60%;

(8) at a displacement of 16m³Min, using 100m³Injecting the linear gel fracturing fluid into a sand carrying fluid, wherein the sand types are 40/70-mesh low-density ceramsite, 30/50-mesh low-density ceramsite and 20/40-mesh low-density ceramsite; the sand ratios were 14% respectively; 16 percent; 16 percent; the linear gel fracturing fluid consists of 0.3% of thickening agent, 0.3% of cross-linking agent, 1% of demulsifying agent, 0.5% of seepage-absorption oil displacement agent, 0.1% of gel breaker and the balance of water. Wherein the emulsion breaker is an aqueous solution of a compound of alkylphenol polyoxyethylene sodium sulfate, aminotrimethylene phosphonic acid and diethylene glycol ethyl ether, the ratio of the components is 3:1:2, and the total concentration is 60%; the imbibition oil displacement agent is an aqueous solution of a compound of fatty alcohol polyoxyethylene ether carboxylate, polyoxyethylene oleate and ethylene glycol monobutyl ether, the proportion of the components is 3:2:2, and the total concentration is 70%;

(9) displacing 60m³And stopping pumping after water is slipped.

Example 3:

the well C is a volatile oil reservoir well with the well depth of 3720m and the vertical depth of 2520m, and the modification method of one section of the reservoir comprises the following steps:

(1) collecting data such as physical properties and logging data of the reservoir, including acoustic time difference, density, natural potential, natural gamma logging curve, elastic modulus of the reservoir, horizontal ground stress X, horizontal ground stress Y, Poisson's ratio of reservoir rock, original pore pressure of the reservoir, thickness of the reservoir, regional ground stress and the like;

(2) comprehensively considering parameters such as natural crack directions, intersection relations, regional stress fields, rock physical properties and the like, establishing a complex phase state flow model of the multi-scale crack by using Fracman software and adopting methods such as Mote Carlo random crack simulation, risk simulation, finite element Mesh use, post-processing output and the like, wherein the established model comprises a far well water-reducing water-making long crack area, a middle acid liquid etching strengthening seepage area and a near well proppant filling area, simulating and calculating stress values and stress field changes under different crack spacing conditions through Intech software, and performing pumping for parameter and model fitting optimization;

(3) pump injection program design, combining the phase state change rule of the oil reservoir seepage interval, and optimizing pump injection parameters according to the data in the step (2);

(4) the field construction process flow comprises the following steps: at a displacement of 2m³Min injection 20m³Pretreating the stratum with acid liquor; the acid solution comprises, by mass, 18% of hydrochloric acid (the concentration of the hydrochloric acid is 25%), 1.5% of a corrosion inhibitor, 1.5% of an iron ion stabilizer, 1.5% of a clay stabilizer and 1.5% of a cleanup additive, and the balance of water.

(5) At a discharge capacity of 10m³Permin injection slick water 100m³(ii) a The slickwater comprises, by mass, 0.08% of resistance reducing agent, 0.5% of emulsion breaking preventing agent and 0.3% of anti-swelling agent, and the balance of water. The emulsion-preventing demulsifier is an aqueous solution of a compound of alkylphenol polyoxyethylene sodium sulfate, aminotrimethylene phosphonic acid and diethylene glycol ethyl ether, and the weight ratio of the components is 2:2:2, and the total concentration is 60%.

(6) At a displacement of 13m³Min, using 650m³Injecting a sand-carrying liquid into the slickwater, wherein the sand type is 70-140 meshes of low-density ceramsite, and the sand ratio is 3-10%; the slickwater comprises, by mass, 0.08% of resistance reducing agent, 0.5% of emulsion breaking preventing agent and 0.3% of anti-swelling agent, and the balance of water. Wherein the drag reducer and the anti-swelling agent are commercially available products, the emulsion breaker is an aqueous solution of a compound of alkylphenol polyoxyethylene sodium sulfate, aminotrimethylene phosphonic acid and diethylene glycol ethyl ether, the ratio of the components is 2:3:2, and the total concentration is 70%.

(7) At a displacement of 13m³Min injection 400m³Reducing the resistance of the acid; wherein the resistance reducing acid consists of 18 percent of hydrochloric acid (the concentration of the hydrochloric acid is 25 percent), 0.08 percent of acid liquid resistance reducing agent, 1.5 percent of corrosion inhibitor and 1.5 percent of phase permeation improver, and the rest is water. The acid liquor resistance reducing agent is a compound of polyvinylpyrrolidone and polydiallyldimethylammonium chloride, wherein the average molecular weight of the polyvinylpyrrolidone is 80 ten thousand, the average molecular weight of the polydiallyldimethylammonium chloride is 50 ten thousand, the ratio of the polyvinylpyrrolidone to the polydiallyldimethylammonium chloride is 7.5:2.5, the phase permeation improver is an aqueous solution of a compound of polyoxyethylene ether, flutolanil and sodium carbonate, the ratio of the components is 3:2:3, and the total concentration is 80%.

(8) At a discharge capacity of 15m³Min, using 85m³Injecting the linear gel fracturing fluid into a sand carrying fluid, wherein the sand types are 40/70-mesh low-density ceramsite, 30/50-mesh low-density ceramsite and 20/40-mesh low-density ceramsite; the sand ratios are 12% respectively; 15 percent; 14 percent; the linear gel fracturing fluid consists of 0.25% of thickening agent, 0.25% of cross-linking agent, 0.8% of demulsifying agent, 0.3% of imbibition oil displacing agent, 0.08% of gel breaker and the balance of water. Wherein the thickening agent, the cross-linking agent and the gel breaker are commercially available products, the emulsion breaker is an aqueous solution of a compound of alkylphenol polyoxyethylene sodium sulfate, aminotrimethylene phosphonic acid and diethylene glycol ethyl ether, the ratio of the components is 2:2:2, and the total concentration is 60%; the imbibition oil displacement agent is an aqueous solution of a compound of fatty alcohol polyoxyethylene ether carboxylate, polyoxyethylene oleate and ethylene glycol monobutyl ether, the proportion of the components is 2:2:1, and the total concentration is 50%.

(9) Displacement of 80m³And stopping pumping after water is slipped.